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Home My WebLink About214-1757. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 07-07C Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-175 50-029-20901-02-00 14396 Conductor Surface Intermediate Liner Liner 8886 80 2457 2496 6811 5100 14004 20" 13-3/8" 9-5/8" 7" 4-1/2" 8886 36 - 116 34 - 2491 32 - 2796 2639 - 9450 9294 - 14394 36 - 116 34 - 2490 32 - 2793 2638 - 8466 8335 - 8887 14004 (3) 470 2670 4760 5410 7500 14004 1490 5380 6870 7240 8430 9450 - 14070 4-1/2" 12.6# 13Cr85 29 - 9302 8466 - 8987 Structural 4-1/2" HES TNT Perm 8235 9176 8235 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 , 0028308 294 1667 24770 41919 34 626 0 0 368 885 324-148 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 9176 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 29 - 8342 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.05.03 11:12:26 - 08'00' Eric Dickerman (4002) By Grace Christianson at 1:34 pm, May 03, 2024 RBDMS JSB 051424 WCB 7-29-2024 DSR-5/6/24 ACTIVITYDATE SUMMARY 4/1/2024 ***WELL FLOWING ON ARRIVAL*** PULLED DREAMCATCHER FROM 9212' MD (EMPTY). ***WSR CONTINUED ON 4-2-24*** 4/2/2024 ***CONTINUED FROM 4-1-24*** RIG DOWN SLICKLINE. ***WELL S/I ON DEPARTURE*** 4/2/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Venturi, Drift/Log, 3 Ext Adperfs Mobilize & MIRU CTU 9 ***Continue on WSR 4/3/24*** 4/3/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Venturi, Drift/Log, 3 Ext Adperfs RU CTU 9. MU BOT 3.60" Venturi BHA. FP Flowline 87 bbl diesel. Kill well w/ 283 bbls slick 1% kcl w/SL. RIH. Venturi through heel and perf section down to 13,875'. POOH pumping slick KCL w/double safelube. POOH ***Continued to WSR on 4/4/24*** 4/4/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Venturi, Drift/Log, 3 Ext Adperfs Finish POOH w/3.6" BOT Venturi. L/D tools, recovered apx 2 cups of debris in venturi, 3 slip segments, 2 larger pieces of rubber and various small debris. M/U BOT shorty MHA and HES GR/CCL. Btm Stop 13,875.12' HES. Log up 50 fpm. WHITE FLAG 13,249.96' HES. Log Up 50 fpm. Top Stop 8999.88' HES. POOH. Kill Well w/ 315 bbl slick 1% kcl w/ SL. Keep well full OOH. MIRU Crane, HES TCP. NO FLOW Good. Drinking ~ 0.7 to 0.8 bpm. Do continues hole fill 0.5 bpm w/ slick 1% kcl w/ SL. BD HES Mem Tools. Good data +31' Correction. PT 3500 BOT MHA w/ Swivel. Deploy 21 HES 2-7/8" MaxForcre guns. MU FH & RIH pump keep well full. Working down Perf Guns starting 12,227' to Flag depth. Correct depth at flag, RIH past shot depth then PU and perforate 13,300-13,353', 13,382-13,768' with HES 2- 7/8" MaxForce guns 6spf, 60 degree phasing. POOH while pumping pipe displacement. Weights were erratic while POOH, attempted to RBIH at 165' and had to work pipe to guns to go down. RBIH to troubleshoot. ***Job Continued on WSR 4/5/24*** 4/5/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Venturi, Drift/Log, 3 Ext Adperfs Continue to troublshooting weight issues before pulling into tree with guns. POOH and lay down gun run #1. Cut CT and change off Pack-offs. RIH w/ HES 2.9 carrier w/ 3.25" DJN. Btm Stop @ 12,949.93' HES box. Log up 50 fpm. Yellow Flag @ 12,409.79' HES box. Log up 50 fpm. Top Stop @ 10,000.07' HES box. POOH. Kill Well and monitor for losse ~.4BPM to the well. Maintain cont. hole fill and deply gun run #2. Confirm +4' correction with OE. RIH with 416' of 2-7/8" Max Force guns 6spf 60 degree phasing (332' loaded). ***Job Continued on WSR 4/6/24*** Daily Report of Well Operations PBU 07-07C gg perforate 13,300-13,353', 13,382-13,768 Daily Report of Well Operations PBU 07-07C 4/6/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Venturi, Drift/Log, 3 Ext Adperfs Continue RIH with gun run #2. Correct depth to top shot at flag, RIH past perf depth then pull into position. Perforate intervals 12,462-12,537' and 12,593-12,850' with HES 2-7/8" MaxForce guns 6spf, 60 degree phasing. POOH while pumping at 1 BPM to keep hole full. Flag pipe at 11,900'e while POOH for next gun run. Undeploy gun run #2. Deploy 22 guns 500'. MU FH. RIH. Corrected depth at flag and perforated intervals 11,930' - 12,120' & 12,260' & 12,430'. POOH while pumping keep hole full. Undeploy gun run #3 and FP well with 38bbls of diesel. RDMO CTU ***Job Complete*** 4/7/2024 LRS Well Testing Unit #2, begin WSR 4/7/24, Post Coil fill cleanout, Flowback, Unit Move, RU, PT 4/8/2024 LRS Well Testing Unit #2, begin WSR 4/7/24, Post Coil fill cleanout, Cont. RU, PT, Flowback. Continue WSR on 4/9/24 4/9/2024 LRS Well Testing Unit #2, Contiune WSR From 4/8/24,IL 07-07, OL 07-05 Post Coil fill cleanout, Flowback. Continue WSR on 4/10/24 4/10/2024 (FREEZE PROT) Assist Well Testers. FP 07-05 FL for Well Testers outlet well. Pumped 5 bbls 60/40 and 88 bbls crude down 07-05 FL Pressure up to 1500 Psi. DSO notified upon departure. 4/10/2024 LRS Well Testing Unit #2, Contiune WSR From 4/9/24,IL 07-07, OL 07-05 BD,RD, Unit move. End WSR on 4/10/24 g Perforate intervals 12,462-12,537' and 12,593-12,850' All adperfs are correctly shown on the new WBS, below. -WCB gyg perforated intervals 11,930' - 12,120' & 12,260' & 12,430 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 07-07C Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-175 50-029-20901-02-00 ADL 0028309 , 0028308 14396 Conductor Surface Intermediate Liner Liner 8886 80 2457 2496 6811 5100 14004 20" 13-3/8" 9-5/8" 7" 4-1/2" 8886 36 - 116 34 - 2491 32 - 2796 2639 - 9450 9294 - 14394 2430 36 - 116 34 - 2490 32 - 2793 2638 - 8466 8335 - 8887 14004 (3) 470 2670 4760 5410 7500 14004 1490 5380 6870 7240 8430 9450 - 14070 4-1/2" 12.6# 13Cr85 29 - 93028466 - 8987 Structural 4-1/2" HES TNT Perm No SSSV Installed 9176 Date: Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY 4-1-2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov / 8235 By Samantha Coldiron at 3:13 pm, Mar 06, 2024 324-148 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.05 12:58:39 - 09'00' Bo York (1248) DSR-3/6/24MGR20MAR24 10-404 2430 A.Dewhurst 08MAR24JLC 3/20/2024 CT Extended Add Perfs 07-07C PTD: 214-175 Well Name:07-07C API Number:50-029-20901-02-00 Current Status:Operable Rig:Coil Estimated Start Date:4/01/24 Estimated Duration:3 days Regulatory Contact:Carrie Janowski 564-5179 Permit to Drill Number 214-175 First Call Engineer:Jerry Lau (907) 564-5280 (O)(907) 360-6233 (M) Second Call Engineer:Dave Bjork (907) 564-4672 (O)(907) 440-0331 (M) Current Bottom Hole Pressure:3310 psi @ 8,800 TVD 7.3 PPGE | (Average Ivishak BHP) Maximum Expected BHP:3310 psi @ 8,800 TVD 7.3 PPGE | (Average Ivishak BHP) Max. Anticipated Surface Pressure:2430 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2350 psi (Taken on 2/7/21) Min ID:3.70 LNR Obstruction @ 11,989 CTMD Max Angle:110 Deg @ 14261 MD Tie In Log:07-07C 2015_07_29 BPXA PDCL LOG Brief Well Summary: 07-07C is a natural flow Rotary Sidetrack lateral drilled in 2015. Its currently a Sag/Z2A/Z2B producer withZ2A toe perfs isolated with a CIBP. Production is competitive GOR at 75k, but low rate due to limited perf footage. It is expected that a gas underrun limited the vertical standoff from GOC leading the previous operator to shoot only 272 of the 3500+ lateral. We believe gas coning was accelerated by the limited perf intervals. 3 of 4 plugs were milled in February 2024 to set the well up for additional perf footage to be shot. Objective: Add 1131 of Z2A/Z2B perforations using the CT open hole deployment system. Procedure: Slickline Pull dreamcatcher Coiled Tubing Notes: Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. CT Extended Add Perfs 07-07C PTD: 214-175 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Load well with 1% KCL/SW down TBG. Max tubing pressure 2500 psi. This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS. a. Wellbore volume to top perf = 144 bbls i. 4-1/2 TBG/LNR 9450 X 0.0152 bpf = 144 bbls b. LNR volume from top perf to CIBP = 69 bbls i. 4-1/2 LNR 4554 X 0.0152 bpf = 69 bbls 3. MU and RIH with logging tools and drift BHA: 2-7/8 dmy gun & nozzle. 4. Flag pipe as appropriate per WSS for 3 perf runs. 5. POOH and freeze protect tubing as needed. 6. Confirm good log data. 7. At surface, prepare for deployment of TCP guns. 8. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 10.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2-7/8 Maxforce guns. Job calls for a total of 1131 of loaded guns and 225 of spacer/blanked pipe to be shot over 3 runs. Perf Interval (RUN 1)Loaded (ft) Blanks (ft) Interval Length (ft) Weight (lbs) 12.41 lbs/ft 13300 - 13353 53 0 53 658 13353 - 13382 0 29 29 360 13382 - 13768 386 0 386 4790 Total 439 29 468 5808 CT Extended Add Perfs 07-07C PTD: 214-175 Perf Interval (RUN 2) Loaded (ft) Blanks (ft) Interval Length (ft) Weight (lbs) 12.41 lbs/ft 12462 - 12537 75 0 75 931 12537 - 12593 0 56 56 695 12593 - 12850 257 0 257 3189 Total 332 56 388 4815 Perf Interval (RUN 3) Loaded (ft) Blanks (ft) Interval Length (ft) Weight (lbs) 12.41 lbs/ft 11930 - 12120 190 0 190 2358 12120 - 12260 0 140 140 1737 12260 - 12430 170 0 170 2110 Total 360 140 500 6205 11. RIH with perf gun #1 and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesnt fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 14. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 15. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 16. Repeat steps 11-15 for runs 2 and 3. 17. RDMO CTU. 18. RTP or FP well. Well Testers Perform an initial flowback of 1 day of stabilized production through a portable well test separator to clean up perf debris. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Coil Tubing BOPE Schematic 4. Standing Orders for Open Hole Well Control during Perf Gun Deployment 5. Equipment Layout Diagram 6. Tie In Log 7. Sundry Change Form - Make up PCE. - mgr CT Extended Add Perfs 07-07C PTD: 214-175 Current Wellbore Schematic CT Extended Add Perfs 07-07C PTD: 214-175 Proposed Wellbore Schematic CT Extended Add Perfs 07-07C PTD: 214-175 Coiled Tubing BOPs CT Extended Add Perfs 07-07C PTD: 214-175 Standing Orders for Open Hole Well Control during Perf Gun Deployment CT Extended Add Perfs 07-07C PTD: 214-175 Equipment Layout Diagram CT Extended Add Perfs 07-07C PTD: 214-175 Tie In:07-07C 2015_07_29 BPXA PDCL LOG (Gamma Ray only) CT Extended Add Perfs 07-07C PTD: 214-175 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the first call engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Operations Manager Date Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 07-07C Mill CIBPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-175 50-029-20901-02-00 14396 Conductor Surface Intermediate Liner Liner 8886 80 2457 2496 6811 5100 14004 20" 13-3/8" 9-5/8" 7" 4-1/2" 9004 36 - 116 34 - 2491 32 - 2796 2639 - 9450 9294 - 14394 36 - 116 34 - 2490 32 - 2793 2638 - 8466 8335 - 8887 14004 (3) 470 2670 4760 5410 7500 14004 1490 5380 6870 7240 8430 9450 - 14070 4-1/2" 12.6# 13Cr85 29 - 9302 8466 - 8987 Structural 4-1/2" HES TNT Perm , 9176 , 8235 No SSSV Installed 9176 8235 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 29 - 8342 285 583 19170 16757 1 631 0 0 332 395 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations , 0028308 By Grace Christianson at 1:24 pm, Mar 05, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.05 12:33:28 - 09'00' Bo York (1248) WCB 2024-06-25 DSR-3/5/24 RBDMS JSB 031324 ACTIVITYDATE SUMMARY 2/22/2024 T/I/O = 320/1450/40. Temp = 74°. Bleed IAP to 850 psi (Coil request). ALP = 1460 psi, AL online. IA FL @ 5820' ( sta# 3, Dome). Bled IA to production to 830 psi in 1 hr. Monitored for 30 min. IAP decreased 10 psi, IA FL unchanged. Final WHPs = 320/820/40. SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:30 2/23/2024 LRS CTU #2 1.75" CT. 0.156" WT, HS-95. Job Scope: Mill CIBP's. MIRU CTU. Pump 1.25" Drift Ball. Perform Weekly BOP Test. Recover Drift Ball. Freeze Protect Flowline w/ 100 bbls Crude. Bullhead 125 bbls 1% KCL down Tbg. RIH w/ Baker 3.70" Venturi/Burnshoe Milling BHA. Tag upper CIBP at 9862'. Begin milling on plug, not seeing any motor work and stacking weight. While milling on plug found a small leak lubricator connection. While troubleshooting leak plug let go, lost returns and well goes on vac. Start POOH to swap lubricator. Come to surface check tools remove lubricator joint w/ leak and replace w/ x2 5' sections. All tools look good no plug recovery. Make up tools back up, PT lubricator and RBIH. ***In Progress*** 2/24/2024 LRS CTU #2 1.75" CT 0.156" Wall Job Scope: Mill CIBPs Continue RIH w/ 3.70" Venturi/Burnshoe Milling BHA. Tag upper plug @ 9880' CTM and begin milling. Push plug down to next plug at 11928' CTM. Mill on top of plug for ~1.5 hrs. Pooh. Recover majority of upper CIBP slips and milling debris. No core recovered. Clean Venturi and Re-run 3.70" Venturi/Burnshoe. Tag 2nd CIBP at 9023'. Attempt to burnover the upper CIBP core. ~ 85% returns while milling. Pooh to check tools. Freeze Protect Coil w/ Diesel. Nothing recovered. Re-run Venturi/Burnshoe with braided wickers. Tag at 11921'. Attempt to burnover CIBP core. Pooh to check tools. Freeze Protect Coil w/ Diesel. Core not recovered. Swap BS to one w/ small ID and RBIH. While RIH 2500' w/ Venturi/BS identify hydraulic leak at injector head. POOH to investigate. Drain fluid from sump and clean. Reseal sump and restack riser. WELL CONTROL, MAN DOWN and H2S drills ***In Progress*** 2/25/2024 LRS CTU #2 1.75" CT 0.156" Wall Job Scope: Mill CIBPs Finish cleaning injector sump and reseal. Restack riser and PT. RIH w/ Baited Overshot (grapple range: 2.02" - 2.1875"). Tag/stack down at 11926'. Hit down jar lick. Pooh. Recovered CIBP Core. RIH w/ Baker Venturi + 3.70" Burnshoe Milling BHA. Tag 2nd CIBP at 11921'. Mill on plug for over 2hrs with no success. Pooh to check Tools. Burnshoe still in good shape. Coil shaving in venturi basket. Clean up tools swap burn shoe and RBIH. Tag 2nd CIBP 11924'. Mill on plug for ~1hr and start to push downhole. Push plug down to plug #3 12978' CTM. Spin on plug and stack weight no motor work. POOH to inspect tools. Bit stuck @ 11979' CTM. Able to work through and continue OOH. ***In Progress*** Daily Report of Well Operations PBU 07-07C Tag/stack down at 11926'. Hit down jar(g g ) g j lick. Pooh. Recovered CIBP Core. RIH w/ Baker Venturi + 3.70" Burnshoe Millingg BHA. Tag 2nd CIBP at 11921'. Mill on plug for over 2hrs with no success. Pooh togg check Tools. Burnshoe still in good shape. Coil shaving in venturi basket. Clean upgg tools swap burn shoe and RBIH. Tag 2nd CIBP 11924'. Mill on plug for ~1hr andg start to push downhole. Push plug down to plug #3 12978' CTM Continue RIH w/ 3.70" Venturi/Burnshoe Milling BHA. Tag upper plug @ 9880' CTMggg@ and begin milling. Push plug down to next plug at 11928' CTM. Mill on top of plug forgg g g g ~1.5 hrs. Pooh. Recover majority of upper CIBP slips and milling debris. No corejy g recovered. Clean Venturi and Re-run 3.70" Venturi/Burnshoe. Tag 2nd CIBP at 9023'. Daily Report of Well Operations PBU 07-07C 2/26/2024 LRS CTU #2 1.75" Coil 0.156 WT Job Scope: Mill CIBPs Continue POOH w/ Venturi/BS. Retrieved slips and misc. plug parts but no core. Swap and re-run new 3.70" Burnshoe. Reciprocate across obstruction at 11988' ctm. Dry tag CIBP at 12976'. Attempt to burnover core from the 2nd CIBP or 1hr. Pooh to inspect tools. Perform Man Down Drill w/ Crew. Recovered 2nd CIBP Core. Stack down & change packoffs. RIH w/ Baker 3-1/8" Venturi + 3.70" Burnshoe. Mill plug #3 @ 12960' MD and push to plug #4 @ 14004' MD (14010' CTM). Stack weight and spin on plug to burn over core. POOH, No over pulls coming OOH. FP well w/ 38bbls diesel. Did not recover Core, recovered several slip and milled plug remnants in venturi. RDMO ***Job Complete*** 2/27/2024 ***WELL S/I ON ARRIVAL*** (Mill underream) RAN 4 1/2" BLB & 3.80" GAUGE RING TO BRUSH X NIPPLE @ 9,212' SLM ***CONTINUED ON 2/28/24 WSR*** 2/28/2024 ***CONTINUED FROM 2/27/24 WSR*** (Mill underream) SET 4 1/2" DREAM CATCHER @ 9,212' MD ***WELL S/I ON DEPARTURE*** Milled CIBP fish(es) is correctly shown on the new WBS, below. -WCB RIH w/ Baker 3-1/8" Venturi + 3.70" Burnshoe. Mill plug #3gg @ 12960' MD and push to plug #4 @ 14004' MD (14010' CTM). Stack weight and@g@ spin on plug to burn over core. POOH, Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:214-175 6.50-029-20901-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 14396 9880 8795 9176 none 8235 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1490 470 Surface 2457 13-3/8" 34 - 2490 34 - 2490 5380 2670 Intermediate 2763 9-5/8" 32 - 2795 32 - 2793 6870 4760 Liner 6812 7" 2639 - 9450 2638 - 8466 7240 5410 Perforation Depth: Measured depth: 9450 - 14070 feet True vertical depth:8466 - 8987 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr85 29 - 9302 29 - 8341 9176 8235Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 5100 4-1/2" 9294 - 14394 8335 - 8887 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1129039319 017364 0 40094 317 848 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564 -5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8886 Sundry Number or N/A if C.O. Exempt: n/a no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028309 PBU 07-07C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 9880,11914,12960,14004 By Samantha Carlisle at 10:45 am, Mar 01, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.02.25 15:59:02 -09'00' Bo York RBDMS HEW 3/1/2021MGR01MAR2021DSR-3/1/21 ACTIVITYDATE SUMMARY 2/1/2021 T/I/O = 2350/450/10. Temp = SI. TBG FL (E-Line). AL SI @ casing valve (680 psi). TBG FL @ 9200' (140 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:10 2/6/2021 ***WELL SHUT IN ON ARRIVAL*** MIRU E-LINE SET NS CIBP AT 9880' ATTEMPT TO PERFORATE, FIND BAD DETONATOR ***JOB CONTINUES ON 07FEB21*** 2/6/2021 T/I/O=2000/900/0 Temp=SI Assist E-line (Perforating) Load tbg. Pumped 3 bbls of 60/40 and 170 bbls of crude down the tbg to load. FWHP=150/450/0 E-Line still on well upon departure. 2/7/2021 ***JOB CONTINUES FROM 06FEB21 WSR*** PERFORATE FROM 9454' - 9485' (reference log depth 9450 - 9481) WITH 3.125" 6SPF 60PHASE HSC W/GEO BASIX XDP CHARGES RDMO E-LINE ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE Daily Report of Well Operations PBU 07-07C Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:214-175 6.50-029-20901-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 14396 11914 9031 9176 none 11914,12960,1400 8235 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1490 470 Surface 2456 13-3/8" 34 - 2490 34 - 2490 5380 2670 Intermediate 2796 9-5/8" 32 - 2795 32 - 2793 6870 4760 Liner 6811 7" 2639 - 9450 2638 - 8466 7240 5410 Perforation Depth: Measured depth: 10386 - 11296 feet True vertical depth:9036 - 9033 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr85 29 - 9302 29 - 8342 9176 8235Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 5100 4-1/2" 9294 - 14394 8335 - 8887 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 976041277 4938822 0 29256 453 1093 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564 - 5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8886 Sundry Number or N/A if C.O. Exempt: Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028309 PBU 07-07c 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:41 am, Oct 12, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.10.09 15:40:18 -08'00' Bo York SFD 10/12/2020 RBDMS HEW 11/13/2020 SFD 10/12/2020 DSR-10/12/2020MGR13OCT2020 , ADL 028308 ACTIVITYDATE SUMMARY 9/25/2020 ...Well shut in on arrival... (HES Eline - drift & perf) DRIFT WITH 22' x 3-3/8" DUMMY PERF GUNS (3.66" swell rings) TO 10,180'. PERFORATE 10,070'-10,090' WITH 20' x 31/8" HSC LOADED WITH 22.7G GEODYNAMIC RDX CHARGES. REFERENCE LOG: BP PDCL 29-JUN-2015. REFERENCE LOG DEPTHS: 10,700' - 10,900'. ***Job Complete. Well shut in on departure, handed over to DSO to POP*** 9/25/2020 T/I/O= 2400/300/0. LRS Unit 72 assist E-Line. (PERFORATING) Pumped 58 bbls of crude into the TBG. Final T/I/O= 1500/300/0 Daily Report of Well Operations PBU 07-07C 10070'-10090' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development RI Exploratory ❑ 5. Permit to Drill Number. 214-175 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigraphic ❑ Service ❑ 1 6. API Number: 50-029-20901-02-00 7. Property Designation (Lease Number): ADL 028309 5 0283088. Well Name and Number: PBU 07-07C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: RECEM Total Depth: measured 14398 feet Plugs measured 11914, 12960, 14004 feet true vertical 8886 Effective Depth: measured 11914 feet Junk feet Packer measured None feet JUN 2 6 2019 measured 9176 feet true vertical 9031 feet Packer true vertical 8235 feet A ®G C C Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" 36-116 36-116 1490 470 Surface 2457 13-3/8" 34-2491 34-2490 5380 2670 Intermediate 2763 9-5/8" 32-2795 32-2793 6870 4760 Liner 6812 7" 2639-9450 2638-8466 7240 5410 Liner 5100 4-1/2" 9294-14394 8335-8887 8430 7500 Perforation Depth: Measured depth: 10386 - 14070 feet True vertical depth: 9036-8987 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 29-9302 29-8341 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 9176 8235 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 390 41024 41 0 932 Subsequent to operation: 366 31188 44 0 969 14. Attachments: (required per 20MC25.070.25.071,&25280) 15. Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development RI Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil EI Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Authorized Name: Thompson, Ryan Contact Name: Thompson, Ryan Authorized Title: Interventions Engineer Contact Email: RYAN.THOMPSONabp.com Authorized Signature: k--- 7 ` //4? -'2 Date: 6 /r?� / I Contact Phone: +1 907 564 4535 Form 10.404 Revised 09/2017 "e 2sv yrw � -3BDMS19,,✓JUN 2 8 2019 „eSubmit Original Only Ic Daily Report of Well Operations PBU 07-07C ACTIVITYDATE SUMMARY CTU #9.1.75" Coil - 0.156" wt Objective: Log, Adperf Arrive on location, MIRU. Make up 2.4" GR/CCL carrier with 3.50" JSN drift nozzle and RIH. Load well with Safelube while RIH. Tag CIBP at 11926' CTMD and log up to 9000' painting tie in flag at 11000'. Confirm +1' correction and CIBP depth of 11924' MD. POOH. Makeup pert gun run #1 with with 32.5' of 2.75" Millenium HMX pert guns, 6 spf and RIH. Tie in to CIBP and perforate 11264- 11296'. POOH. 6/1/2019 ..Continue on WSR 6-2-19... CTU #9. 1.75" Coil - 0.156" wt Objective: Log, Adperf POOH with Perf gun run #1. Make up perf gun run #2 with with 32.5' of 2.75" Millenium HMX pert guns, 6 spf and RIH. Tie in to CIBP and_perforate 10911'-10943'. POOH. All shots fired, ball recoverd. Perform seven day BOP test, RDMO to SLB yard, 6/2/2019 ...Complete... Tri= ' 4-1116'ClW NH! BEAD MCEVOY ACTLATOR BAKER OKB. ELEV , 64' BE BEV = _9 KOP= 28W Max An* = 110' @ 14261" Dalen MD= 9973' DalumTVD; 8800 SS .5#, 14-40, = 19.124' 18- BOWEN CSC PATCH, D=9.630' rl 1992-- 13-3/8- CSG, 72X, L-80 BUTT, D = 12.347' 7 1 9-5/8' CSG, 47#, L-80 BUR, D = 8.681' 1—j —2795' I Minimum ID = 3.70" @ 11989' 4-112" LNR OBSTRUCTION IESTMATEDTOPOFCBv1DJT I .0152 bpf, ID = 3.958' TOP OF 4-12' LNR ID = 6.276" I 9294' I PERFORATION SUM IVARY REF LOG: MGR/ CCL ON 0622115 ANGLEATTOPPERF: 81'@ 103W Note: Refer to Production DB for Historical pert data SIZE SPF WTHRVAL Opm'SW SHOT SQZ 2-3/4' 6 10386 -10406 0 0624/18 3624 2-34' 6 10911 -10943 O 06/02/19 BK 2-3/4' 6 11264 -11295 O 06/01/19 5397 2-3/4' 6 11950 - 11982 C 11/04/17 18 2-3f4' 6 12430- 12462 C 11/04/17 33 2-314' 6 12688 - 12720 C 11/04/17 06/03/15 2-314' 6 13670- 13680 C 03/18/17 KBG2 2-3/4' 6 136'90- 13700 C 03118/17 2-3/4' 6 13768 -13800 C 03/17/17 2-7/8" 6 14050-14070 C 0622/15 .0152 bpf. ID = 3.958' SAFETY NOTES:- @ 10W�L ANGLE >70* @ 10258" MAX 07-07C DOGLEG 9-5/8' HES ES CB4RnER --� 2016' 614-12'HPSXNP,D=3.813° 2352' 13-3l8' FOC 2478' 13-3re•Foc 2638' 9-518' X 7' BKR HRD-E ZXPN LTP w / TIEBK, ID = 6.20' 2654' 9-5/8' X 7- BKR FLEX -LOCK HGP, D = 6.22' MLLOUT WINDOW (07-070) 2795' -2817' GAS LFT aMhOfLS ST MD TVD DEV TYPE VLV T PORT DATE 4 3624 3547 31 KBW DOME BK 16 106109115 06/24/18 JCF/JMD TAR OBST, SET CBP, ADU FS 3 5820 5397 33 KBG2 DOME BK 18 07/07/17 2 7310 6550 33 KBW DMY BK 0 06/03/15 1 8673 7800 30 KBG2 DW BK 0 06103/15 9145' 4-12-HMXNP,D=3.813' 9176- —17 -X4 -12 -HES TNT WK D= 9212' 4-12'OTISXNP,D=3.813' INITIAL (07-07A) 06/72I75 ATC11 RJC FEiFOROMM 06/30106 NOMC I CTD (07-078) 9284' 4-12' OTB XN NP, D ISMO TT NOT LOGE® 9305' 7'XS'BKRHRDXPN LTP,D=4.34' 9318' 7 X 5- BKR OG FLEX -LOCK HGR. D = 4.34' 932W 5- X 4-12" XO, D = 3.93" DATE REV BY COM MWS DATE REV BY COMMENTS 03/31183 INITIAL (07-07A) 06/72I75 ATC11 RJC FEiFOROMM 06/30106 NOMC I CTD (07-078) 07/21/15 TR'JMD 4-12'LPRCOf?R6f,TIOPS 06106115 614 SIDETRACK(07-07C) 03Y10/l7JTMJMDSETCSP&AD-BZFS(03f17-16117) 06/09/15 DLtV PJC GLV C/O 07/10/17 BSF/JMD GLV 40(07/07/17) OSIlG/15 PJC DRLG HOCORRECTKM& 06/24/18 JCF/JMD TAR OBST, SET CBP, ADU FS 07/06115 BG/ PJC FINAL ODEAPPROVAL 06/05/19 JIM'JMD AD UT -S 06/01-02/19) WFT CBP (06/24/11 2UCD)N. D = 3.70' PRUDHOE BAY LM W LL: 07-07C PERMIT W: 1141750 AR W: 50-029-20901-02 T11 N, R14E, 1347' FNL & 138' FEL BP Eglloration (Alaska) nc6„01C,IVGU • STATE OF ALASKA NOV 2 $ 7 ALASKA OIL AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OPERATIONS AC 1. Operations Performed Abandon 0 Plug Perforations DJ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate H Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other:Set CIBP Ed 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 214-175 3. Address: P.O.Box 196612 Anchorage, Development IBJ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20901-02-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-07C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 14396 feet Plugs measured 12960/14004 feet true vertical 8886 feet Junk measured feet Effective Depth: measured 12960 feet Packer measured 8906 feet true vertical 9048 feet Packer true vertical 8001.77 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 36-116 36-116 1490 470 Surface 2457 13-3/8"72#L-80 34-2491 34-2490 4930 2670 Intermediate 2763 9-5/8"47#L-80 32-2795 32-2793 6870 4760 Production Liner 5100 4-1/2"12.6#13Cr8 9294-14394 8335-8887 8430 7500 Liner 6812 7"26#L-80 2639-9450 2638-8466 7240 5410 Perforation Depth: Measured depth: 11950-11982 feet 12430-12462 feet 12688-12720 feet 13670-13680 feet 13690-13700 feet 13768-13800 feet 14050-14070 feet True vertical depth: 9031-9030 feet feet 9034-9035 feet 9041-9042 feet 9041-9041 feet 9041-9041 feet 9040-9037 feet 8993-8987 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 29-9032 29-8111 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNE r to 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 211 16338 25 575 360 Subsequent to operation: Shut-In 525 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development Q Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Meixueiro,Paulina Contact Name: Meixueiro,Paulina Authorized Title: Production Engineer- Contact Email: paulina.meixueiro@bp.com Authorized Signature: 1 lJ...... . 11,....,..,-.43Date: i('2 g I.Zoll Contact Phone: +1 907 564 5971 Form 10-404 Revised 04/2017 7 fV� /217-1/ 7-- 1 ��p��+ �� 7/1 RBDTAS [,c--- NOV 2 9 2317 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary November 28, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Cast Iron Bridge Plug and Addition of Perforations for Well 07-07C, PTD # 214-175. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Packers and SSV's Attachment PBU 07-07C SW Name Type MD TVD Depscription 07-07C PACKER 1971.82 1970.99 9-5/8" BOT External CSG PKR 07-07C PACKER 2649.59 2648.62 _7" Baker ZXP Top Packer 07-07C TBG PACKER 8905.8 8001.77 4-1/2" HES TNT Perm Packer 07-07C PACKER 9305.56 8344.53 5" Baker ZXP Top Packer • r N > a N O) co N N � _0U) -a DN a) N °o ° ° W II O 3 ri o C -TD o ° Ib p o_ N o O O V) O o (NI szt 0 o O)) O O J = p o_ a) -Y N ai L N p > o o N o O D Cl N _0 > U 0IT) a) - Cr . 0 cc [l O C co C a > O I- (o O ( co N Q c- O T c N O a) Q >N O D ° O 0 U CO C a.CD d N O 't N ° C E co O co O) O a ca L o o z c co a - UL c) I- O mo ,_ E -ate 0 L \ C LaN � Q co N 00 .E L O a) O cu O a) U II a) a) -a n a) E +, cC Q= = D LII- d °- - u) Q D QU CU Q < m E pU S a) Q o Q CQco E a) L2no > QUnp < aa)L eL DQ W, \ L O > \ -2 L N \ a) v/ > O. N m ° ~ a- coc D m `- a) o - a) m o po U u) c� o U W > J -0 N E m 0 F- U L -a a) J O W U cp U C * 7 0 71) O C i a) C 'c \ 0 LL O (0 O C C a)Q Q a) a) ai O J Q c L -o J a) 00 J 6 4_ -c J .C- o M .P, L O Q O Dt Ca .o U) d _ N 1-l) -c 0) N - a Q Q U O S Q O Q c0 d N E Q O a) Z N co I-6 > O) O IZ D = u) p I- > ° o a) LD . E xQ Da Q. Q _ N U a O (� P V1 *k C In O 5 a) O re a o = * - W u) Q Q Q � a) l'-- nn N o U M r w LO > O m w _0 o 0)-7: N ° OU c _o >+ cn - rn <- Q � Uco -0u) a V) � � u) a a :'" .0 In cS N M LJL C Q U N C _0 Q co = in _0 J Q ti L -cp p -0 O r O) .N O) p C Q N ( u) -, CN X \ ao -, a) c0 N cu C.L N = - > O <- u)4 112 L M - M Q (n U °) U a op O > U ° U x S .0 oU Z m O ~ ca - EC) (Ni O a) C C _J Eo CT) N - a 72 i-- O4N- u) 05 - N4C) 7 Q ca N (� N- D .a)J apo mi-- a) N-(7)' Na) DN- >, E Y _ Y I- 0)U C co 0 CO _, u) ui co I 3 c a) a) - co c..) JD cN u) ° do E -0 oco W \ ._ ccoJ o 2 2o _ \V. 0 \ I- W * \ .- U) H S p C U l- D O 2 x I- O p L p C.) 1 E : 1- rncn0c o o : Uc W o 00— co t...) W I- 1 N- N- N- r- } O O O O O y CO N CO N N N N N r- p 5 N N M IC) m N N \ \ U Q TREE= 41116"CNH • 07-07C�J C WELLHEAD MCEVOY t 0 •f C_0 7 SOV NOTES: WELL ANGLE>70°@ 10258'"'"MAX 4CTUATOR BAKER C DOGLEG:12°@ 10745'"." OKB.ELEV' 64' BF.EiEV= ? , 1949' H 9-518"FES Es CEMENTER 20'CCNdDUCTOR, H 119' ___ . _ KOP= 2800' 1972' __^I-�5/8'EXTERNAL CSG PKR I Max Angie= 110°©14261" 91.5#,1+40, �►� ___- Datum MD= 9973' D=19.124" ' 2016' --i4-1/2"HES X NP,D=3.813" Datum TVD 88(}0`SS [9_5/8"CSG,47#,L-80 V A M TOP,D=8.681" -L 1992' 1 __---1 2362' H13-3/8"FOC 9-5/8'BOWE4 CSG PATCH,D=9.830" H 1992'-1996' 2478' 13-3/8'FOC 13-3/8"CSG,72#,L-80 BUTT,D=12.347' H 2496' 2638' -9-5/8'X 7'BKR I-*O-E ZXPN LTP W/TEBK, [TOP of 7 LNRx 2638• I 4ID=6.20" [9-5/8"WF1PSTOCK(05/04/15) H 2796' 2664' 1-19-5/8'X 7"BKR FLEX-LOCK HGR,D=6.22" I 9-5/8'CSG,47#,L-80 BUTT,D=8.681" -2796' � IrILOUT WFNDOW(07-07C)2795'-2817 GAS LMT MANDRELS Minimum ID = 3.725" @ 9284' ST MD TVD DEV TYPE VLV _ATCF PORT DATE 4-112" MIS XN NIPPLE 4 3624 3547 31 KBG2' DOME BK 16 06/09/15 3 5820 5397 33 KBG2 DOME BK 16 07/07/17 2 7310 6650 33 KBG2 DMY BK 0 06/03/15 1 8673 7800 30 KBG2 DMY BK 0 06/03/15 9146' H41/2'FES XNP,D=3.813' LES_ TINA I to TOP OF CEMENT H 7960' �t k 0 + I 9176' 7"X 41/2-FES TNT PKR,D=3.856"i 9212• --14-1/2'OTIS X Imo',D=3.813" :r 9284' 14-1/2'OTIS XN NP!D=3.725' 4-112'TBG,12.6#,13CR-85 VAM TOP, H 9302' '.1 ' t .0152 bpf,D=3.958" ' _929_1'_a--I 7"X 5"TEBACK-1V,D= " [TOP OF 4-1/2"LNR(C33 tTEd) I- 9294' j k ' �- L___9302' I-4-1/2"WLEG,D=3.958" I I . I-iELNDTT NOT LOGGED "'vvv�� '+. 9306' H7'X 5"BKR i-RD XPN LIP,D=4.34"J 7'LNR,26#,L-80 VA TOP HC, -{ 9450' I� 9318' -17'X 5"BKR DG FLEX-LOCK HGR,D=4.34' .0383 bpf,D=6.276' .✓+ *4 9328' -15'X 4-1/2"XO,D=3.93"[ PERFORATION SUMMARY --* �� kir -10800 4-1/2"RA PP TAB(2ND) REF LOG:MGR/CCL ON 06/22/15 y f _I--[,_ ANGLE AT TOP PERF:90° 7 11950' A" Note:Refer to Reduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2-3/4" 6 11950-11982 0 11/04/17 wl► 2-3/4" 6 12430-12462 0 11/04/17 ♦ •.• 12900' j-4-1/2'RA PPTAB(1ST) I iv 2-3/4" 6 12688-12720 0 11/04/17 �+ 12960' -14-1/2"WFTCBP(ttro3/17) I 2-3/4" 6 13670-13680 C 03/18/17 le = -_ 2-3/4" 6 13690- 13700 C 03/18/17 0.5.0 2-3/4' 6 13768-13800 C 03/17/17 - 2-7/8' 6 14050-14070 C 06/22/15 [ 14004'_-4-1/2'W DCFBP(03/17/17) PBTD - 14308' IlA - 4-1/2"LNR,12.6#,13CR-80 VAM TOP, --I 14394' ' 0000 .0152 bpf,ID=3.958' DATE REV BY COMMENTS DATE REV BY COMANTS PRUDHOE BAY UNIT 03/31/83 BNITIAL(07-07A) 06/22/15 ATO/PJC PERFORATIONS WELL: 07-07C 06/30/06 NORDIC 1 CTD(07-07B) 07/21/15 TR/AD 4-1/2"LNR CORRECTIONS PERMIT No:t141750 06/06/15 D-14 SIDETRACK(07-07C) 03/20/17 JTMJMD SET COP&ADPERFS(03/17-18/17) API No: 50-029-20901-02 06/09/15 DLW PJC GLV CIO 07/10/17 BSE/JMD GLV C/O(07/07/17) SEC 33,T11N,R14E,1347'ENL&138'FEL 06/10/15 PJC DRLG HO CORRECTIONS 07/06/15 BG/PJC FINAL ODE APPROVAL BP Exploration(Alaska) • 23\0 WELL LOG TRANSMITTAL#903910942 To: Alaska Oil and Gas Conservation Comm. RECEIVED^ ``c June 12, 2017 Attn.: Makana Bender EC OI' G 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 JUN 2 2 2017 °ATA LOGGED oGR f M.K.BENDER RE: Coil Flag Log: 07-07C AOGCC Run Date:3/15/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari,Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 07-07C Digital Data(LAS),Digital Log file(Field Data) 1 CD Rom 50-029-20901-02 Coil Flag Log(Field Print) 1 Color Log 50-029-20901-02 SCANNED .JUL 1 J2017 PLEASE ACKNOWI FDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:? �'nrit. ..0.4t ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations fid Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: ( J f3 P (3s 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 214-175 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20901-02-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PRUDHOE BAY UNIT 07-07C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: A Total Depth: measured 14396 feet Plugs measured 14004 feet RECEIVED■ E I VE true vertical 8886 feet Junk measured feet 11i•V r Effective Depth: measured 14004 feet Packer measured 8906 feet APR 1 1 1 2017 true vertical • 9004 feet Packer true vertical 8001.77 feet U ! AOGCCCasing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 36-116 36-116 1490 470 Surface 2457 13-3/8"72#L-80 34-2491 34-2490 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 13670-13680 feet 13690-13700 feet 13768-13800 feet 14050-14070 feet True vertical depth: 9041-9041 feet feet 9041-9041 feet 9040-9037 feet 8993-8987 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 29-9032 29-8111 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): ��yy MAY cr`k Treatment descriptions including volumes used and final pressure: $CANNED MAY 1 20i?. • 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 233 18835 19 450 802 Subsequent to operation: 227 19543 22 400 809 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1i71 Exploratory 0 Development Ed Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ ❑ WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 4/10/17 Form 10-404 Revised 5/2015 c-4//k" 5/1 ° ig" RBDMS .: APR 1 2 2017 Only ..,'((e/. Submit Original • • a) Q o 0 0 0 0 0 0 (DcOco � o3 — � cOl� l� v � �n C N V Lc) U Tn. o 0 0 CD 0 CD 0 i- C) Cr) I- N- CO N 3 O) CO CO N O Ca r V CO CO N- CO O) O CO CO CO I, - Cfl O o CA CO 00 N N CO 00 CO I I I I I I 1 H N CO CC') CO N 0) Cr) CO O) M CO Cr) 0) CO co N N Co C ti CD p COCn O a N E l (Drnrnrn �r) (,) cY 0) vO •O ' (N '- N0) . 0) ai i I i i I i i 4.1Zco M co CN O) M 0)) 0) co co co 0) CO N N } '- N C) __ QM • W W O Cf) C2 C2 0 O p0 O O • T v Co ao U U T = J J CO _ a) C -r•- *k *k . = N C1) (` *k CO co • - - - N N CA b e0 U a �, , , - O (,;) N N t O Cr) O CO co N 0 0 C Co - O) O CO r O N CO 10 Cr) W W — — 0 C W a N U W W Et z Z W w W W m O D ~ ~ Z Z D O w Z Z J J H • Packers and SSV's Attachment PRUDHOE BAY UNIT 07-07C SW Name Type MD TVD Depscription 07-07C PACKER 1971.82 1970.99 9-5/8" BOT External CSG PKR 07-07C PACKER 2649.59 2648.62 7" Baker ZXP Top Packer 07-07C TBG PACKER 8905.8 8001.77 4-1/2" HES TNT Perm Packer 07-07C PACKER 9305.56 8344.53 5" Baker ZXP Top Packer 0 ,, • � I . 4-' = fe / \ \ \ � J § ¥ ° / \ = o - 2 / 0 / \ ±D \ § , ® $ / c / 0- ° G / G C 0 § \ % \ = f Zee\ '3E 2a � E2eE- -5 te « e r o / / cii 0 / $ ° / \ e ,% $ 5 / c 1 , / Ea) F / R / / \ 0 / 0 \ / / 0)/ % / \ - \ © % � / 0 � � \ a ' 2 / f / Z co-- / © La ƒ 01046 _0 ? .\ ƒ / a O e 6 o n c/ � .R e z < � $ 2 \25- c ,- 7b2 5 2 2 o_> 2 5 E m I R .§ cfi / / / \ % / CJ CO / ƒ 7 2 � ƒ / \ / �� k ) -c.c 2 E o co ■ 9 < U � a U . .. .4— \ Ee \ / K - / \ 0 /) % CL R O L L E ri % L / \ a) cn p � 2 2 Io E_ o _ o I � 27 = - / / i .& / ® � / / 2 f ƒ � - (a 0 t 9 / \ t / / @ b -I t / $ $ o 1 < < * E® I ƒ o \2 f O \ a \.f E R a) / < / / 5 < 0 13 d E $ .k < % 0 / * a « % \ \ a E o O 2 % 6 2 \ : 0. O > 2 2 m o -I 2 o E_ $ o e » ± = 2 • 3 / :ƒ k /2 — $ Qrb / % \ EfE2 > _ j— a w = a • Z). 0 ° (T)o - e c o 0 >IfX ® w w O » / § P O 0 G e O ._ t 2 co u_ / ƒ / \ / c / 0 0)0 = 2 \ / \ 0 § / b / ti CI $ < 2 I__ « f e I•12 \ .7 » / O \ /# % c # 5 \ 2 . r I o— R G = o R .§ § b e 2@ / ƒ k / \ ® ° / / / E d \ \ / \ f $ - 0 O r q R5 = o ._ r E . -J —I n 2 w • CO 9 \ C 2 w u # 4 2 aL o ( w g \_ / E / U ± R w O > 0 .7 w I [ cw >_, \ % \ 0 q § F & G r -CO 2 § 3 b S 7 ± ± I- J / D E � g / U 0 \ \ /CO4, a9...). -, (0 -- - ® § / Et / / - c,2 £ e $ / q = 0 / co \ / § % / ) / k / t f : 0 : O 2 r & n 3 I U * = e ,- a O U 2 E : : b 2 y 2 U w / r-- w w w w w CO ® (NI / ƒ \ / \ � / b � $ / CO® 0 « @ 6 A @ @ < • TREE= 4-1/16"CNV 0 ACTUATOR BAKMCEVOY R2C 0 7_0 7C SASAFETYGLEGNOTS 2°@10 745WELL ANGLE>70°@ 10258'"""MAX OKB.H_EV: 64' _ ' • 1 1949' J--19-5/8"FES FS CEM LATER , _ BF.ELEV- ' 20"CONDUCTOR 119` KOP= 2800' 91.5#'H-40 1 1972' 1-19-5/8 EXTERNAL CSG PKR i Max Angle= 110°@ 14261" 13=19.124" Datum MD= 9973' ' 2016' H4-112"HES X NP,D=3.813" 1 'Datum TVD: 8800'SS 1 9-5/8"CSG,47#,L-80 VAM TOP,ID=8.881" I-1 1992' I 2352' H13-3/8"FOC [9-5/8"BOWEN CSG PATCH,D=9.830" - 1992'-1996' 2478' -13-318"FOC 13-3/8"CSG,72#,L-80 BUTT,D=12.347" - 2496' 2638' -9-5/8'X 7"BKR HRD-E ZXPN LTP w/TEBK, TOP OF 7"LM - 2638' 1 D=6.20" 9-5/8"WHPSTOCK(05/04/15) 2796' Y---- 2664' 9-5/8"X 7"BKR FLEX-LOCK HGR D=$22" 1 9-5/8 CSG,47#,L-80 BUTT,D=8.681" j-j -2795' 1 MILLOUT WINDOW(07-07C)2795'-2817' GAS LFT MANDRELS Minimum ID = 3.725" @ 9284' ST MD TVD DEV TYPE VLV .ATCI- PORT DATE 4-1/2" OTIS XN NIPPLE 4 3624 3547 31 KBG2 DOME BK 16 06/09/15 3 5820 5397 33 KBG2 SO BK 20 06/09/15 2 7310 6650 33 KBG2 DMY BK 0 06/03/15 1 8673 7800 30 KBG2 DMY BK 0 06/03/15 9146' 1-4-1/2"HES X NP,D=3.813" 1 ESTIaiA I Ell TOP OF CEMENT --I 7950' w i. 9176' 7"X 4-1/2"HES TNT PKR,D=3.856"' 9212'l -I4-1/2"OTIS X NP,ID=3.813" i4 �} Il 9284' -14-1/2"OTIS XN MP,D=3.725" 4 4-1/2'TBG,12.6#,13CR-85 VAM TOP, H 9302' ' I 0152 bpf,D=3.958' 1 9294' -H7"X 5 TEBACK 11' ID "J ." ' IL TOP OF 4-1/2"LNR(CEMENT D) - 9294' , ' 9302' -�4-1/2 WLEG,D=3.958" HELM TT NOT LOGGED i.-.4..4•. 9306' 1-7'X5"BKRFRDXPNLTP,D=434" .� . 1 f+* 9318' -1 T X 5"BKR DG FLEX-LOCK HGR D=4.34" A.t. t; 9328' S"X 4-1/2"XO,D=3.93"' t . T LNR,26#,L-80 VAM TOP HC, -( 9450' --.......,4,,;,.. ,' _.__......._..___.____ .0383 bpf,ID=6.276" � .v * * 1 -10800 1-14-112"RA PP TAB(2ND) 1 PERFORATION SUMMARY *-* REF LOG MGR/CCL ON 06122/15 4..4, ,- 12900' [-[4-1/2"RA RP TAB(1ST)i .., ► ANGLE AT TOP FEW:90°@13670' +- , -- Note-Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 4.4 r. 2-3/4' 6 13670-13680 0 03/18/17 2-3/4" 6 13690-13700 0 03/18/17 t V Aid 2-3/4" 6 13768-13800 0 03/17/17 2-718" 6 14050- 14070 C 06122115 ;+, +* .1.."‘ 14004' j—{4-1/2 WFD CEP(03/17/17) I.1.."‘ I I PBTD - 14308` ,~.'s 4-1/2"LNR 12.6#,13CR-80 VAM TOP, H 14394' 1----4'...z.' . .0152 bpf,ID=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/31/83 IIMTIAL(07-07A) 06/22/15 ATO/PJC PERFORATIONS WELL 07-07C 06/30/06 NORDIC 1 CTD(07-07B) 07/21/15 TR/JMD 4-1/2"LNR CORRECTIONS PERMT No 2141750 06/06/15 D.14 SIDETRACK(07-07C) _03/20/17 JTMJMD SET CIBP8ADPERFS(03/17-18/17) AR No: 50-029-20901-02 06/09115 DLIV PJC GLV C/O SEC 33,T11 N,R14E 1347'M.&138'FEL 06/10/15 PJC DRLG HO CORRECTIONS 07/06/15 BG/PJC FINAL ODE APPROVAL BP Exploration(Alaska) • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - 17_5' Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Maps. tp/Gayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: '!. Date: I L I Ol/5 /s/ riqP Project Proofing BY: Maria Date: ii/i ./io /s/ PIP Scanning Preparation x 30 = I Sb + 1 L- =TOTAL PAGES i qq- BY: Date: ' I /a /,.5- (Count does not include cover sheet) 1ft/) Production Scanning Stage 1 Page Count from Scanned File: / t 5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria ) Date: I ' p�., //S /s/ 1 fliP Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage I + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc 0 • o . N 'n I in I CV o O o CO1 oO CO1 • Z N. N LU N .o LL U 0 • O Z SII C ' N -3 NN E a 0 �'0) .>'E w y N N 0 Z O Z N N O a3 ? •p ? 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U a 0 0 0 c 0 0 • Hunt, Jennifer L (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Thursday, August 20, 2015 2:12 PM To: Hunt, Jennifer L (DOA) Subject: PBU 07-07C/ PTD # 214-175 Hi Jennifer, Please reference the following well: Well Name: PBU 07-07C Permit#: 214-175 API #: 50-029-20901-02-00 Date of Test: 8/14/15 Type of Test: IPT (Initial Production Test) Choke Size: 79 Choke Unit: Production Method: Flowing Duration (Hours Tested): 5 Top Reference (Top Perf MD): 14050' Bottom Reference (Bottom Perf MD): 14070' Tubing Flowing (Pressure): 340 Casing Pressure: 1580 Total Test (Rate f/O, W, G): 333/ 10/ 1122 24-Hour Rate (0, W, G): 1599 /49/5384 Gravity (Oil, API): N/A GOR (Gas-Oil Ratio): 3367 This well began Production on: 8/13/2015 Method of Operations on this date: Flowing 1 RBDNIS1 AUG 2 1 2015 KbUr.{VCM STATE OF ALASKA al4SKA OIL AND GAS CONSERVATION COMMISSIdli JUL 2 1 2015 WELL CNIMPLETION OR RECOMPLETION REPOWND LOG la. Well Status: Oil 0 ' Gas ❑ SPLUG 0 Other 0 Abandoned 0 Suspended 0 lb.Well CasQ"'°""C 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: One • Service ❑ Stratigraphic Test 0 2. Operator Name: 6. DiComp. Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc '6/22/2015 214-175 ' 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 •5/5/2015 50-029-20901-02-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: •5/30/2015 PBU 07-07C - Surface: 1347'FNL,138'FEL,Sec.33,T11N,R14E,UM • 17. Field/Pool(s): 9. KB(ft above MSL): 60.72' ' Top of Productive Interval: 2281'FNL,3524'FWL,Sec.34,T11N,R14E,UM GL(ft above MSL): 26.57' . PRUDHOE BAY,PRUDHOE OIL • Total Depth: 4466'FNL,1910'FWL,Sec.35,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 14308'/8914' - ADL 028309&028308 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 676067- y- 5949575 - Zone - ASP 4 •14396'/8886' • TPI: x- 679752 y- 5948728 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 683472 . y- 5946632 • Zone - ASP 4 None 1900'(Approx.) 5. Directional Survey: Yes IJ (attached) No 0 13. Water Deoth.if Offshore: 21. Re-drill/Lateral Top Window M D/f VD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) •2795'/2793' - 22 Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD/GR/RES,MWD/GR/RES/NEU/DEN ' QI'Alk 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 34' 114' 34' 114' 30" 470 sx Arcticset II 13-3/8" 72# L-80 34' 2490' 34' 2489' 17-1/2" 1600 sx Fondu,400 sx Permafrost'C' 9-5/8" 47# L-80 31' 2795' 31' 2793' 12-1/4" 500 sx Class'G',50 Bbls Permafrost'C',792 sx Class'G' 7" 26# L-80 2638' 9450' 2637' 8466' 8-1/2" 325 sx Class'G' 4-1/2" 12.6# 13CrB0 9294' 14394' 8335' 8887' 6-1/8" 605 sx Class'G' 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2",12.6#,13Cr85 9302' 9176'/8235' 2-7/8"Gun Diameter,6 spf 14050'-14070' 8993'-8987' • 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Wit$i.,fillia Was hydraulic fracturing used during completion? Yes 0 No 0. I, ., Per 20 AAC 25.283(i)(2)attach electronic and printed I A. information r 14' + i DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED "_'� 2000' Freeze Protect w/140 Bbls Diesel 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate ..♦ Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only V7 Z— .1sJ) /440(/,KRBDMS SEP a 2 7015 Li 28. CORE DATA • Conventional Core(s) Yes 0 No l Sidewall Cores Yes 0 No D - If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No lI Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 Ugnu • 4777' 4519' AAC 25.071. West Sak• 6312' 5811' Colville Mudstone • 6784' 8208' HRZ • 8665' 7793' Base of HRZ 8866' 7967' LCU • 8917' 8011' Sag River • 9450' 9466' Shublik • 9490' 8499' Sadlerochit-Zone 4B 9574' 8567' CGL-Zone 3 • 9810' 8743' Base of CGL-Zone 2C 9920' 8824' 23SB-ZONE 2B • 9985' 8868' 22TS 10105' 8938' 21TS-Zone 2A• 10210' 8988' Zone 1B(Fault) 11403' 9032' 21 TS-Zone 2A 11868' 9031' 22TS(Invert) 13965' 9013' 23SB-Zone 2B 14173' 8958' Base of CGL-Zone 2C 14330' 8907' Formation at total depth: Zone 2C(From Base) 14330' - 8907' 31. List of Attachments: Summary of Daily Drilling Reports,Summary of Post-Rig Work,LOT/FIT Summary,Wellbore Schematic,Survey,Cement Reports Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gorham,Bradley M Email: Bradley.Gorham©bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: I Phone: 907-564-4091 Date: //tip/) 5 INST UCTIONS General:This form is designed fo bmitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only 1/16 WELLHEAD 4-MCEV Y • 07-07C 7_07C SA TES:EG 12°@ 10 L ANGLE>70'@ 10258'"""MAX DOGL ACTUATOR BAKER C OKB.ELEV= 64' BF.ELEV= ? * °. ' 1949' ,-19-5/8"1-ES G'J ES ES CRATER 20"CONDUCTOR — 119' KOP= 2800' 1972' —19-5/8"EXTERNAL CSG PKR x Angle= 110°@ 14261" 91.5#,H 40, Ma Datum MD= 9973' D=19.124" ' 2016' —14-112"HES X NP,D=3.813" Datum ND, 8800'SS 9-5/8"CSG,47#,L-80 VAM TOP,D=8.681" H 1992' -1 2352' H13-3/8"FOC 9-5/8"BOWEN CSG PATCH,D=9.830" — 1992'-1996' / 2478' —113-3/8"FOC 13-3/8"CSG,72#,L-80 BUTT,D=12.347" --I 2496' 2638' —9-5/8'X 7'BKR HRD-E ZXPN LTP w/TEBK, TOP OF 7'LNR— 2638' L D=6.20" 9-5/8"WHPSTOCK(05/04/15) H 2795' 2654' --19-5/8"X 7"BKR FLEX-LOCK HGR,ID=6.22" 9-5/8"CSG,47#,L-80 BUTT,ID=8.681" — —2795' MLLOUT WINDOW(07-07C)2795'-2817' Minimum ID = 3.725" @ 9284' \ GAS LFT MANDRELS ST M3 No DEV TYPE VLV ATCF FORT DATE + 4-1/2" (JTIS XN NIPPLE 4 3624 3547 31 KBG2 DOME BK 16 06/09/15 3 5820 5397 33 KBG2 SO BK 20 06/09/15 2 7310 6650 33 KBG2 OMY BK 0 06/03/15 1 8673 7800 30 KBG2 DMY BK 0 06/03/15 I 9145' H 4-1/2"FES X NP,D=3.813" ESTMA i t31 TOP OF CEN'sIT —I 7950' 9176' —I r X 4-1/2'HES TNT PKR,D=3.856' I. 9212' H4-1/2"OTIS X NIP,D=3.813" (t , 9284' .—I4-112"OTIS XN NP,D=3.725" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, —I 9302' ' R .0152 bpf,ID=3.958" 9294' —17"X 5"TIEBACK-11',ID= " TOP OF 4-1/2"LNR(CENENlED) —I 9294' �` . � ` 9302' H4-1/2"WLEG,D=3.958" 1 —BAD TT NOT LOGGED A : 9305' --17'X 5'BKR FRD XFN LTP,D=4.34" 9318' H7'X 5"BKR DG FLEX-LOCK HGR,D=4.34" 7"LNR,26#,L-80 VAM TOP HC; — 9450' .+, 9328' —I5"X 4-112'XO,D=3.93"' fr- .0383 bpf,ID=6.276' '�4' Y PERFORATION SUMMARY p" �' REF LOG:MGR/CCL ON 06/22/15 ANGLE AT TOP FERE 105°@ 14050' Nate:Refer to Production DB for historical pert data + 10800 —14-1/2"RA PIP TAB(2ND) SIZE SPF INTERVAL Opn/Sqz SHOT SOZ y 2-7/8" 6 14050-14070 0 06/22/15 a j, , 12900' —14-1/2"RA RP TAB(1ST) 44 t. f MID --I 14308' '-',4;41 ( *' 4-1/2"LNR,12.6#,13CR-80 VAM TOP H 14394' :� .vim .0152 bpf,0=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/31/83 IIMTIAL(07-07A) 06/22/15 ATO/PJC PERFORATIONS WELL: 07-07C 06/30/06 NORDIC 1 CTD(07-07B) 07/21/15 1R/J14) 4-1/2"LNR CORRECTIONS PERMT No: 2141750 06/06!15 D-14 SIDETRACK(07-07C) AR No: 50-029-20901-02 06/09/15 DLI-V PJC GLV CO SEC 33,T11N,R14E,1347'FNL&138'FEL 06/10115 PJC DRLG HO CORRECTIONS 07/06115 BG/PJC FINAL ODE APPROVAL BP Exploration(Alaska) • .BP AMERICA ,, .,, sJ „2„,,F41,„,„1,,,,,, ,av,,,,,4„,,f0,..1;,`;:z&5e1;g1 .,•*1k. /,, c ''..,,,, 1' s. LOT/ FIT Summary n�, ,, Well Name: 07-07C Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 05/05/15 LOT 2,812.00 2,809.49 9.00 320.00 1,633.53 11.19 05/24/15 FIT 9,475.00 8,473.79 8.50 730.00 4,471.68 10.16 Page 1 of 1 • • North America-ALASKA-BP ,, Page 1 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 ' Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/24/2015 00:00 01:00 1.00 1 MOB P PRE MOVING RIG OFF 03-15B WELL AND SPOT ON THE PAD. ! -PJSM. I-FUNCTION ESD ON THE MOVING SYSTEM. ' I GOOD TEST. 1-DISCUSS ROLES AND RESPONSIBILITIES. I-PULL RIG OFF WELLAND SPOT IN CENTER II OF PAD. : ,*RECEIVE PERMISSION FROM FIELD I i 'SUPERINTENDENT AT 2245 HRS TO MOVE OFF 03-15B WELL WITH 150 PSI ON OA. *PAD OPERATOR WAIVED WITNESS OF RIG 'MOVING OFF WELL 03-15B. 01 00 - 03:00 2.00 MOB P PRE I INSTALL REAR BOOSTERS. 1-PJSM. j -INSTALL REAR BOOSTERS. 1-AIR TIRES. i FUNCTION TEST. 03.00 - 12.00 ' 9.00 MOB P PRE MOVING RIG FROM DS-3 TO DS-7. _ -PJSM. DISCUSS SPECIFIC HAZARDS FOR GOING ACROSS THE ICE ROAD AND WALKING :SURFACES DUE TO POT HOLES IN ROAD. ' MOVE RIG FROM DS-3 TO THE EAST GUARD ISHACK. 12:00 20:00 I 8.00 MOB P ' PRE I MOVING RIG FROM DS-3 TO DS-7. i -CONTINUE TO MOVE RIG FROM THE EAST GUARD SHACK TO DS-15 ACCESS ROAD. *SUBMIT INTENTION TO TEST BOPE ON 07- 07B AT 18:07 HOURS TO THE AOGCC. 20:00 - 00:00 4.00 MOB I P PRE I MOVING RIG FROM DS-3 TO DS-7. I RIG MOVE HALTED DUE TO EXCESSIVE CROWN AND SIDE SLOPE ON OXBOW ROAD, AND RIG TIRES HAVING EXCESSIVE SIDE LOADING. -DECISION MADE TO USE 2 DOZERS TO ASSIST IN BACKING UP OUT OF THE TURN TO ENABLE ROAD MAINTENANCE EQUIPMENT TO SCARF AND BLADE THE AREA OF CONCERN ON THE ROAD. *THE 2 DOZERS REQUESTED AT 2030 HRS. 4/25/2015 00:00 - 02 00 2.00 MOB N WAIT PRE SUPPORT RIG FROM SLIDING WHILE BACKING ONTO FLAT AREA OF ROAD. PJSM WITH SUPPORT CREWAND DOZERS. -IDENTIFY EXCLUSION ZONES AND ASSIGN ROLES AND RESPONSIBILITIES ALONG WITH COMMUNICATION ROLES. -0045 HRS - DOZERS HOOKED UP TO RIG TO PREVENT SLIDING TOWARDS THE EDGE OF THE ROAD WHILE BACKING UP ON ROAD TO ENABLE EQUIPMENT TO CUT CROWN OF ROAD DOWN WITH GRADER AND SCARRIFY ROAD WITH LOADER. ! - HEAVY EQUIPMENT CUT CROWN OF ROAD CAUSED BY BUILT UP SNOW AND SCARRIFY CURVE AT DS 15 ACCESS ROAD ON OXBOW. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 2 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date I From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) ' (usft) 02:00 - 03:00 1.00 MOB P PRE MOVE RIG TO DS 07. 1 '-PJSM,AND DISCUSS ROLES AND I RESPONSIBILITIES. -CONFIRM RADIO COMMUNICATION AND IMOVE RIG F/DS 15 ACCESS ROAD T/DS 07. -ARRIVE ON DS 07 AND SPOT RIG NEAR ENTRANCE TO PAD. 03.00 - 04:00 1.00 MOB P PRE "CONDUCT L2RA MEETING WITH ALL INVOLVED PARTIES BEFORE PROCEEDING ,PAST NORDIC 1. ATTENDEES:DOYON 14 AND NORDIC 1 ,WSL,SITE CONTROL,PAD OPERATOR, DOYON TOOLPUSHERS,AND DOYON SAFETY. THE FOLLOWING TOPICS WERE I I DISCUSSED: >HAZARD IDENTIFICATION WORKSHEET, INCLUDING ADDITIONAL ITEMS 7b,8b,12b. ION APPROVED RA FOR 2 RIGS ON SAME L2PAD. >EGRESS ROUTE TO THE MANIFOLD BUILDING AND MUSTER AREA. >CONTROL OF WORK: i #PERMITS. I #SITE CONTROLLERS WILL UPDATE PAD I OPERATOR AT 0800 HRS&2000 HRS. #DOYON SITE CONTROL WILL CONTACT [NORDIC 1 SITE CONTROL AT 0400 HRS&1600 HRS WITH SHIFT CHANGE PERSONNEL INFORMATION. #NORDIC 1 SITE CONTROL WILL VERIFY WHICH TRUCKS ARE GOING TO WHICH RIG. WOLF PACK LOCATED NEAR FLOWLINE ON DS-15 AND ALL PERSONNEL NOTIFIED TO HEIGHTEN AWARENESS. -NORDIC 1 WILL BE DRILLING WHEN DOYON 14 PASSES BY THEIR RIG. 04:00 - 05:00 1.00 MOB P PRE MOVING RIG PAST NORDIC 1 TO 07-07C WELL. -PJSM -IDENTIFY ROLES AND RESPONSIBILITIES. MOVE RIG TO BACK SIDE OF PAD AND SET 1 DOWN. 05:00 - 06:30 1.50 MOB P PRE REMOVE REAR BOOSTERS. -PJSM,AND REVIEW DDI SOP OF REMOVING BOOSTERS. SIMOPS,FINISH LAYING DOWN RIG MATS IN FRONT OF WELL 07 FOR RIG. 06:30 - 08:00 I 1.50 I MOB P PRE SPOT RIG OVER WELL 07-07C -PJSM AND ASSIGN ROLES AND RESPONSIBILITIES. MOVE RIG UP ON MATS AND LINE UP WITH WELL. -DRILL SITE OPERATOR AND WSL WITNESS RIG BACK OVER WELL. *FUNCTION ESD ON MOVING SYSTEM I BEFORE RIG APPROACHES WELL.GOOD TEST MOVING SYSTEM SHUT DOWN AS DESIGNED. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 3 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task : Code NPT NPT Depth Phase I Description of Operations (hr) (usft) — 08:00 - 09:00 1.00 RIGU P PRE SKID RIG FLOOR INTO DRILLING POSITION AND SECURE -PJSM AND REVIEW DDI SOP,DISCUSS SPECIFIC HAZARDS AND AQUIRE PROPER PERMITS. 1 I-SKID RIG FLOOR AS PLANNED. 09:00 - 12:00 3.00 MOB P PRE I HOOK UP SERVICE LINES TO RIG FLOOR. L.PJSM AND REVIEW DDI SOP FOR I ASSEMBLYING ALL LINES TO RIG FLOOR. -LAY MATS FOR ROCKWASHER I-PULL CONVEYOR#2 INTO POSITION. I-CHANGING OUT SWABS/LINERS ON#2 MUD I PUMP T/6". II "SIMOPS,HARDLINE CREW ASSEMBLE AND I TEST HIGH PRESSURE LINE F/CHOKE SKID T/FLOWBACK TANK T/250,4000 PSI.GOOD 'LEAK TIGHT TEST. . I I'ACCEPTED RIGAT 1200 HRS. 12:00 - 15:30 3.50 WHSUR P WHDTRE RIG UP OF HIGH PRESSURE LINES TO INNER ANNULUS THROUGH CHOKE SKID FOR I PRESSURE TESTING BPV. -PJSM AND REVIEW DDI SOP OF RIG UP OF I i CIRCULATING LINES TO CHOKE SKID AND IA WITH DOUBLE CHECK VALVES BETWEEN WELLAND MUD PUMP. SIMOPS,CONTINUE INSTALL OF#2 i CONVEYOR. PRESSURE TEST CHOKE SKID AND HIGH PRESSURE LINES TO CHOKE SKID 15:30 - 16:30 1.00 i WHSUR P I WHDTRE T PRESSURE TEST CIRC.LINES. -PJSM,REVIEW SOP AND WALK LINES TO •VERIFY PROPER ALIGNMENT. i I-PRESSURE TEST CHOKE MANIFOLD AND I I HIGH PRESSURE LINES FROM TREE TO CHOKE MANIFOLD T/250,3500 PSI.FOR 5 CHARTED MINUTES EACH.GOOD LEAK ' TIGHT TEST. 16:30 - 17:30 1.00 WHSUR j P I WHDTRE CAMERON PERSONNEL MONITOR CONTROL I LINES FOR 1 HOUR AFTER BLEEDING LINES WHILE CREW MONITORS IA.NO FLOW OBSERVED. 17:30 - 18:00 0.50 WHSUR P WHDTRE CONDUCT H2S EVACUATION DRILL,AAR AFTER DRILL. Printed 7/6/2015 11:00:17AM • North America-ALASKA-E3P Page 4 of 71 " � s Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM I Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. I UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 00:00 6.00 WHSUR N DPRB , WHDTRE PUMP THROUGH INNER ANNULUS WITH MUD PUMP TO PRESSURE TEST BPV F/250 LOW T/3500 HIGH FOR 5 CHARTED MINUTES EACH. PJSM AND REVIEW DDI SOP AND DISCUSS EXCLUSION ZONES CONFIRM PRESSURE CROSSCHECK QUESTIONS WITH PROPER RESPONSES FROM CREW. -INSTALL TATTLE TALE HOSE ON TOP OF DRY HOLE TREE MANIFOLD. -OPEN INNER ANNULUS VALVES TO PUMP ITHROUGH,OUTER ANNULUS VALVES TO MONITOR FOR PRESSURE AND DRY HOLE TREE VALVES ON TREE TO MONITOR PRESSURE ON BONNET DURING PRESSURE TEST. -PRESSURE UP T/250 PSI.WITH PASSING RESULTS FOR OPERATIONAL ASSURANCE TEST. PRESSURE UP T/3500 PSI.AND OBSERVE PRESSURE FALLING RAPIDLY AT A RATE OF i 50 PSI.PER MINUTE.ATTEMPT TO PRESSURE UP SEVERAL TIMES WITH SAME RESULTS. NO PRESSURE OBSERVED ON OUTER ANNULUS VALVE,TREE BONNET OR ODS CONTROL LINE.PRESSURE IS UNIFORM WITH IA PRESSURE ON DS CONTROL LINE, PRESSURING UP AND BLEEDING DOWN AT SAME RATE. -SWAP GAUGE(0-5000)WITH SMALLER INCREMENT GAUGE(0-500)ON OUTER ANNULUS TO ENSURE NO PRESSURE IS BUILDING ON OUTER ANNULUS. -PRESSURE UP AGAIN WITH SAME RESULTS AND NO PRESSURE ON OUTER ANNULUS OR ABOVE BPV. CONTACT SUPERINTENDENT AND ODE. DISCUSS PLAN FORWARD WITH NOT BEING ABLE TO ACHIEVE OPERATIONAL ASSURANCE TEST.DISCUSS PERFORMING BARRIER ROLLING TEST TO PROCEED WITH OPERATIONS.ODE DISCUSS PLAN FORWARD WITH ETLAND WTL. 4/26/2015 00:00 - 01:00 1.00 WHSUR N SFAL WHDTRE DEVELOP PLAN FORWARD ON LEAK TIGHT TEST OF BPV. -SEND PLAN FORWARD FOR APPROVAL TO ODE. -APPROVAL RECEIVED TO PROCEED WITH ROLLING TEST FROM TOWN TEAM. Printed 7/6/2015 11:00.17AM • North America-ALASKA-BP 0 Page 5 of 71 4 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _� (usft) 101:00 - 03:00 1 2.00 1 WHSUR P 1 WHDTRE PERFORM ROLLING TEST ON BPV FROM BELOW. [ -PJSM AND REVIEW DDI SOP FOR ROLLING TEST OF BPV FROM BELOW. 11 -ASSIGN ROLES,RESPONSIBILITIES AND 1 REVIEW PRESSURE CROSSCHECK LIST. -WSL,DRILLER AND TOOLPUSHER CONFIRM 1 i IPROPER LINE UP OF CIRCULATING LINES. 1START ROLLING TEST AT 6 SPM AFTER 11 STROKES PRESSURE INCREASED T/500 PSI. CONTINUE ROLLING PUMP AT 1 SPM AND I PRESSURE CONTINUED TO SLOWLY BUILD I TO 600 PSI.WHILE PUMPING AT RATE OF 1 I SPM(.101 BBL PER STROKE)PRESSURE STAYED AT 600 PSI.FOR DURATION OF 5 1 MINUTE TEST WITH NO PRESSURE 1 OBSERVED ON THE OUTER ANNULUS GAUGE 1 AND NO FLOW FROM THE TATTLE TALE HOSE FROM THE TREE BONNET WITH DRY HOLE TREE VALVES OPEN ABOVE THE BPV. 1 !PRESSURE DID BUILD UP ON THE DS I CONTROL LINE FROM 540 PSI.T/560 PSI. I THE CONTROL LINE ON THE ODS HAD ZERO PRESSURE. l -SHUT DOWN PUMPS AFTER A TOTAL OF 17 STROKES AND BLED PRESSURE OFF OF IA AND DS CONTROL LINE. -MONITOR IA AND DS CONTROL LINE FOR ! TEN MINUTES WITH NO PRESSURE OBSERVED ON BOTH CONTROL LINES,THE I 1 OAAND TATTLE TALE HOSE FROM ABOVE 'THE BPV.GOOD LEAK TIGHT TEST. � -INNER ANNULUS DOES BUILD UP TO 60 PSI. AFTER 10 MINUTES DUE TO TOTAL VOLUME ,PUMPED THROUGH IA OF 20.2 BBLS.WHEN CALCULATED VOLUME TO PRESSURE UP TO 3500 PSI.WAS 2.4 BBLS WITH TUBING CUT AT 13,000'MD. ,-ATTACH IA TO BLEED TRAILER AND I I CONTINUALLY MONITOR WHILE PREPPING TO N/D TREE AND N/U BOPE. Printed 7/6/2015 11 00 17AM 110 North America-ALASKA-BP Page 6 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date.6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft).03:00 - 06:00 3.00 WHSUR P WHDTRE NIPPLE DOWN TREE AND ADAPTER FLANGE. -PJSM AND REVIEW DDI SOP ON NIPPLING DOWN TREE. I-CAMERON WELLHEAD PERSONNEL BLEED HANGER VOID AND TERMINATE CONTROL LINES. IA NOT BUILDING ANY PRESSURE. REMOVE ALL BUT FOUR TREE BOLTS FROM TUBING SPOOL. REMOVE REMAINING TREE BOLTS AND LIFT OFF TUBING SPOOL WITH BRIDGE CRANE. PRE RUN CROSSOVER FOR TEST JOINTS WITH 18-3/4 TURNS AND REMOVE. INSTALL TEST DART IN 5""K'STYLE BPV. CAMERON WELLHEAD PERSONNEL I FUNCTION ALL LOCK DOWN SCREWS AND MARK THE FOUR FOR WEAR RING ALONG WITH MARKS OF THE GLAND NUTS POSITION WHEN PROPERLY TIGHTENED. LDS OUT ON TUBING HANGER MEASURE 4" FROM SIDE OF TUBING SPOOL FLANGE AND 3"WHEN ENGAGED ON TUBING HANGER,ALL LDS AND GLAND NUTS TORQUED TO 450 FT/ LBS. 06:00 - 09:00 3.00 WHSUB P WHDTRE 'NIPPLE UP 13-5/8"5M BOPE. PJSM,P/U 13-5/8"5M BOPE STACK WITH BRIDGE CRANES AND SET ON WELL. -TIGHTEN BOPE STACK TO TUBING SPOOL WITH DRILLING SPOOL ON BOTTOM OF BOPE STACK. -INSTALL KILL LINE,TURNBUCKLES,RISER, FLOWLINE WITH FLOWLINE COVERS AND ENVIRO WRAP. SIMOPS,INSTALL NEW SAVER SUB ON TOP DRIVE. 09:00 - 14.00 5.00 BOPSUR P PRE CHANGE BOPE RAMS. j CHANGE OUT TOP RAMS FROM 4 1/2"X 7" VBR TO 9 5/8"FBR. CHANGE OUT BOTTOM RAMS FROM 2 7/8"X 5"VBR TO 3 1/2"X 6"VBR. -FINISH INSTALLING NEW TOP DRIVE SAVER SUB. -13-5/8"5M HYDRIL BOPE STACK CONFIGURED FROM TOP TO BOTTOM WITH HUBBED 13-5/8"5M"GK'ANNULAR PREVENTER WITH 13-5/8"NITRILE ELEMENT, 13-5/8"5M"MPL"HUBBED DOUBLE GATE DRESSED WITH 9-5/8"FBR IN UPPER GATE AND BLIND/SHEAR RAMS IN LOWER GATE, 13-5/8"5M HUBBED DRILLING SPOOL WITH TWO 3-1/8"OUTLETS,ONE 5M 3-1/8"HCR VALVE AND ONE 5M 3-1/8"MANUAL VALVE ON EACH SIDE FOR CHOKE AND KILL LINES, 13-5/8"5M HUBBED SINGLE GATE DRESSED WITH 3-1/2"X 6"VBR AND ONE HUBBED 13-5/8"5M SPACER SPOOL MADE UP TO 13-5/8"5M CIW TUBING SPOOL. Printed 7/6/2015 11:00.17AM IIII North America-ALASKA-BP • Page 7 of 71 Operation Summary Report ,,,,, gip,;- Common Well Name.07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date 6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT 1 NPT Depth Phase I Description of Operations 1 (hr) _ (usft) I 14:00 16:00 2.00 BOPSUR P PRE .RIG UP TO TEST BOPE 1', I 1-PJSM. I ,-R/U TEST EQUIPMENT. -INSTALL X-O'S TO TEST TOP DRIVE,FOSV'S, I BPV DART,AND PERFORM BOP SHELL TEST. *REQUESTED BY AOGCC REP JOHNNIE HILL TO NOTIFY HIM WHEN A SUCCESSFUL BOPE SHELL TEST IS COMPLETE. i- 16 00 - 22:00 6.00 BOPSUR P 1 PRE TEST BOPE 250 PSI LOW 3500 PSI HIGH FOR 5 CHARTED MINUTES. PJSM AND REVIEW DDI SOP AND IDENTIFY PRESSURE CROSSCHECK QUESTIONS WITH PROPER ANSWERS. !-TEST ANNULAR PREVENTER WITH 4"TEST JOINT. , 1-TEST UPR WITH 9 5/8"TEST JOINT. I TEST LPR WITH 4"AND 5 1/2"TEST JOINTS. TEST ALL BOPE INCLUDING BSR,CHOKE MANIFOLD VALVES 1-14,MANUAL AND I HYDRAULIC CHOKES,MANUALAND HYDRAULIC!BOP'S,CHOKE AND KILL MANUAL/HCR VALVES,2-XT-39 FOSV'S,1 4-12"FOSV AND 1 XT-39 DART VALVE. --ALL TESTS CHARTED,SEE ATTACHED BOPE TEST CHARTS. TEST WITNESSED BY AOGCC REP JOHNNIE 22:00 23:00 1.00 BOPSUR P PRE HILL. - R/D BOPE TEST EQUIPMENT. I R/D BOPE TEST EQUIPMENT. -BLOW DOWN CHOKE AND KILL LINES. -M/U XT-39 FOSV TO SAFETY JOINT. 23:00 - 00:00 1 1.00 BOPSUR P PRE 'INSTALL DUTCH RISER 1 1 -PJSM WITH CREW AND DRILL SITE MAINTENANCE. 4/27/2015 00:00 - 01:00 , 1.00 BOPSUR , P I PRE RIG UP AND TEST LUBRICATOR WITH QUICK TEST SUB. I I PJSM FOR ROLES,RESPONSIBILITIES AND HIGH PRESSURE LINES. 1 , -TEST 250 PSI LOW. -TEST 3500 HIGH. 1 EACH TEST HELD FOR 5 CHARTED MINUTES.GOOD LEAK TIGHT TEST. Printed 7/6/2015 11:00:17AM SNorth America-ALASKA-BP 1110 Page 8 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM 1Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 101:00 - 05:00 1 4.00 1 BOPSUR P PRE REMOVE TEST DART AND 5""K"TYPE BPV. I j PJSM WITH RIG CREW AND 3RD PARTY HANDS. -BREAK LUBRICATOR AT QTS AND SET I UPPER PORTION TO THE SIDE ON RIG 1 FLOOR. VACUUM OUT BOPE STACK TO TOP OF HANGER PROFILE. -RETRIEVE TEST DART WITH DRY ROD. r-RE-INSTALL LUBRICATOR AND TEST QTS CONNECTION 250/3500 PSI.GOOD LEAK 1 TIGHT TEST. -ENGAGE 5""K'TYPE BPV AND OBSERVED 50 PSI.WITH 0 PSI.ON IA. 1-UNABLE TO COMPLETELY SET DOGS ON BPV TO PULL FREE,DUE TO SUSPECTED DEBRIS FROM RAM CAVITIES. WHEN TEST DART PULLED OBSERVED DEBRIS IN TEST DART. *CONFIGURATION OF RETRIEVING TOOLS DOES NOT ALLOW THE BPV TO BE ABOVE THE BLIND/SHEAR RAMS WHEN TOOL I , 'ASSEMBLY FULLY RETRACTED IN LUBRICATOR. 05:00 - 06:30 1.50 BOPSUR P l 1 DECOMP I CIRCULATE THE DIESEL FREEZE PROTECT I OUT OF WELLBORE WITH DUTCH RISER AND LUBRICATOR ON WELL. PJSM WITH CREWAND REVIEW DDI SOP 10N CIRCULATING TO FLOWBACK TANK BLOWAIR THROUGH HARDLINE TO FLOWBACK TANK TO ENSURE NO OBSTRUCTIONS.CONFIRM CLEAR. -LINE UP TO PUMP 250 BELS.120°8.5 PPG SEAWATER THROUGH KILL LINE DOWN I TUBING TAKING RETURNS TO FLOWBACK TANK FROM IA THROUGH CHOKE SKID. -PUMPING AT 250 GPM WITH 300 PSI. 06 30 - 07 00 0.50 BOPSUR P DECOMP 1REMOVE BPV AND R/D DSM LUBRICATOR. -REMOVE THE BPV FROM THE DSM LUBRICATOR. -R/D DSM LUBRICATOR EQUIPMENT AND REMOVE FROM THE RIG FLOOR. 07.00 - 08:30 1.50 BOPSUR P DECOMP ORGANIZE EQUIPMENT ON THE RIG FLOOR. -REMOVE ALL TOOLS NOT ASSOCIATED WITH UPCOMING OPERATIONS. -MOB BAKER SPEAR ASSEMBLY FOR PULLING THE HANGER TO THE RIG FLOOR. 08 30 - 09.00 0.50 1 BOPSUR ! P DECOMP INSTALL 4"ELEVATORS. -PJSM. -INSTALL 4"ELEVATORS. -PICK UP JOINT OF 4"DP,CROSSOVER,AND SPEAR ASSEMBLY. -M/U TOP DRIVE. ENGAGE THE SPEAR INTO THE HANGER AND PULL 15K LBS OVER TO CONFIRM ENGAGEMENT. 09:00 - 09:30 0.50 BOPSUR P DECOMP BACK OUT LOCK DOWN SCREWS ON TUBING HANGER. -CAMERON B.O.L.D.S.AND TIGHTEN GLAND i NUTS TO 450 FT/LBS. Printed 7/6/2015 11.00:17AM IIINorth America-ALASKA-BP • Page 9 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _I (usft) • 09:30 11:00 1.50 BOPSUR P DECOMP PULL TUBING HANGER. 1 1-TOOK 135K LBS TO PULL FREE. I-CONTINUE TO P/U HANGER 10'@ 100K LBS. 1-START CIRCULATING @ 168 GPM=100 PSI, 210 GPM=200 PSI,252 GPM=280 PSI,294 GPM=350 PSI. -SHUT PUMPS DOWN AND MONITOR WELL i ,FOR 10 MINUTES. 11:00 - 12:00 1.00 PULL P ' DECOMP FINISH PULLING HANGER TO RIG FLOOR @ 100K LBS. PJSM ON HAZARDS AND RESPONSIBILITIES. REMOVE 2 BANDS AND DISCONNECT I CONTROL LINES. -REMOVE SPEAR AND BREAK DOWN ASSEMBLY. 1-REMOVE HANGER FROM RIG FLOOR. `FLUID LOSS FOR TOUR=0 BBLS. 12:00 - 13:00 1.00 PULL P DECOMP LAY DOWN 5 1/2"TUBING. -PJSM FOR L/D 5 1/2"TUBING. 1-CHANGE OUT ELEVATORS. 1-INSTALL 5 1/2"LIFT SUB ON SAFETY JOINT FOR WELL CONTROL. 13:00 - 15:30 2.50 PULL P DECOMP POOH 5 1/2"TUBING AND CONTROL LINES. -POOH ON ELEVATORS F/2,960'MD T/830' , i MD 5 1/2"12.6#L-80 AB-M 8RD TUBING. • I ;-SLB SPOOL CONTROL LINES ONTO SPOOLER TO THE SSSV. 1 i *SLB CHECKED FIRST 10 JTS FOR RADIATION WITH NORM METER. TUBING -- NOT HOT. 15 30 - 16:00 0.50 PULL P 1 DECOMP I R/D SLB SPOOLER,L/D TUBING HANGER. -R/D SLB SPOOLER AND ASSOCIATED EQUIPMENT. I-L/D HANGER. 16.00 17:00 1.00 PULL P DECOMP I CONTINUE TO UD 5 1/2"TUBING F/830'MD. -EQUIPMENT PULLED OUT OF HOLE. 70 FULL JOINTS -24 CLAMPS -2 STAINLESS STEEL BANDS. -1 CUT JOINT 4.17' -1 SSSV -1 GLM OD ON CUT JOINT=6 1/4" 17:00 - 19:00 2.00 CLEAN P DECOMP CLEAN CASING TOOLS AND CLEAR RIG FLOOR. -BREAK DOWN SAFETY JOINT. -L/D XO'S FOR WELL CONTROL. 19:00 - 20:00 1.00 WHSUR P 1 DECOMP iNSTALL WEAR RING. -PJSM -INSTALL WEAR RING. ID=91/4" 20:00 - 22:00 2.00 CLEAN P I DECOMP M/U CLEAN OUT 8 1/2"BHA FOR 9 5/8" CASING. 1 -PJSM. I -M/U BIT,BS WITH PORTED FLOAT,MILL, BUMPER SUB,OIL JAR,X-O SUB,6 1/4"DRILL COLLARS,X-O SUB FROM PIPE SHED T/219' MD. Printed 7/6/2015 11 00•17AM • North America ALASKA-BP Page to or 71 Operation Summary Report Common Well Name 07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UVVI:500292090100 Active datum.07-07C actual tt60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations ' (hr) (usft) 22.00 - 00:00 2.00 CLEAN P DECOMP P/U 4"DP SINGLES FROM PIPE SHED. -P/U 4"DP SINGLES FROM PIPE SHED AND RIH F/219'T/2,530'MD. *FLUID LOSS FOR TOUR=6 BBLS. 4/28/2015 00 00 01:00 1.00 CLEAN P DECOMP 1 P/U 4"DP SINGLES FROM PIPE SHED. CONTINUE P/U 4"DP SINGLES FROM PIPE SHED AND RIH F/2,530'T/2,973'. MONITOR TRIP IN THE HOLE ON TRIP TANK- OBSERVED CORRECT DISPLACEMENT "HELD D1 TRIP DRILL,CRT 2 MIN. 01.00 - 03:00 2.00 CLEAN P DECOMP SLIP/CUT DRILL LINE. -PJSM. SLIP/CUT DRILL LINE. -SERVICE AND INSPECT TOP DRIVE, BLOCKS,AND DRAWORKS. CALIBRATE BLOCK HEIGHT AND FUNCTION COM.COM FUNCTIONED AS DESIGN. *SAVER SUB WAS REPLACED WITH NEW SAVER SUB WHEN RIG MOVED OVER WELL, NO NEED FOR INSPECTION AT THIS TIME. 03:00 - 03:30 0.50 CLEAN P DECOMP RIH AND TAG TUBING STUB. -PJSM AND REVIEW DDI SOP. -RIH PICKING UP 4"DRILL PIPE FROM PIPE SHED F/2,973' AND TAG STUB AT 3,004'MD. 03:30 - 04:30 1.00 CLEAN P DECOMP PUMP HI-VIS SWEEP. -M/U TOP DRIVE AND ESTABLISH CIRCULATION AT 650 GPM W/1400 PSI. PUMP 30 BBL.HI-VIS SWEEP AND PUMP OUT OF HOLE WITH NOTHING SIGNIFICANT BROUGHT TO SURFACE. -SHUT DOWN PUMPS AND FLOW CHECK I WELL FOR 10 MINUTES.CONFIRM NO FLOW. -MW-8.5PPG SEA WATER IN/OUT 04:30 - 05:30 1.00 CLEAN P DECOMP POOH WITH 8-1/2"CLEAN OUT ASSEMBLY. -PJSM AND REVIEW DDI SOP. BREAK OUT TOP DRIVE AND BLOW DOWN SAME. -POOH STANDING BACK 4"DRILL PIPE F/ 3,000'T/314'MD. -MONITOR WELL 10 MIN PRIOR TO PULLING NON SHEARABLES ACROSS THE STACK -POOH MONITORING TRIP ON TRIP TANK- CORRECT ANKCORRECT HOLE FILL OBSERVED 05 30 - 07:00 1.50 CLEAN P DECOMP PULL&LAY DOWN 8-1/2"CLEAN OUT BHA. -MONITOR WELL BEFORE BRINGING NON-SHEARABLES INTO BOPE STACK PJSM AND REVIEW DDI SOP OF LAYING DOWN BHA. -POOH AND STAND BACK LAST STAND OF 4" DRILL PIPE F/314'T/219'MD. -UD 6-1/4"DRILL COLLARS AND BHA COMPONENTS AS DIRECTED BY THE BOT REP. Printed 7/6/2015 11:00:17AM IP North America-ALASKA Page11 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay j Site:PB DS 07 Rig Name/No.:DOYON 14 j Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual t 60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT j NPT Depth Phase Description of Operations (hr) (usft) 07:00 - 12:00 5.00 CLEAN r P DECOMP I DRILL PIPE MANAGEMENT. -PJSM FOR DP MANAGEMENT,REVIEW DDI PROCEDURE AND DISCUSS POTENTIAL J DROPPED OBJECTS. J -P/U AND M/U STANDS IN MOUSEHOLE WITH 4" XT39 DP SINGLES 1 X 1 FROM THE PIPE I SHED AND STAND BACK IN DERRICK FOR A I TOTAL OF 81 STANDS IN DERRICK. -CLOSE BLIND/SHEAR RAMS IN CASE AN UNFORESEEN PROBLEM OCCURS WHEN I I SWITCHING POWER FROM GENERATORS TO 4 HI-LINE POWER. I-ONCE CONFIRMED FROM ELECTRICIANS THAT SWITCHWASFLAWLESS OPENED HCR I CHOKE AND FLOWCHECK WELL FOR 10 MINUTES AND OPEN BLIND/SHEAR RAMS. j-DRAIN STACK AND BLOW DOWN CHOKE I LINE AS PER DDI SOP. **SIMOPS**. j-PJSM WITH CPS AND RIG SUPPORT CREW ON SWITCHING TO HI-LINE POWER. I-NOTIFY DS 07 DSO AND GIVE NORDIC 1 COURTESY CALL OF INTENT TO SWITCH TO 1 HI-LINE POWER. *RIG PLACED ON HIGHLINE POWER AT 11:30 ON 04/28/2015. ---------- 12:00 - 14 30 2.50 EVAL P ' DECOMP I SLB ELINE ON LOCATION- 1-PJSM WITH SLB ELINE UNIT AND I� PERSONEL,REVIEW DDI PROCEDURES FOR RIG UP,DISCUSS HAZARADS ASSOCIATED WITH ELINE RIG UP.LIFTING TOOL INSPECTIONS.REVIEW WELL CONTROL REQUIREMENTS SPOT UNIT AND BEGIN BRINGING TOOLS TO THE RIG FLOOR. -RIG UP USIT TOOL WITH GR,CCL RIH AND TEST NO PRESSURE CONTROL REQUIRED FOR USIT RUN,RIH WITH LINE WIPER AND HYDRAULIC CUTTING UNIT -UNABLE TO TEST TOOL WOULD NOT SPIN *PRIMARY DEPTH CONTROL LOG TAKEN: DEPTH WAS ZERO'D AT CURRENT RIG FLOOR SFAL 14:30 - 15:00 0.50 EVAL N DECOMP USIT SUB WOULD NOT SPIN AT CORRECT SPEEDS. I-SLB TROUBLE SHOOTING PROBLEM. 15.00 17:30 2.50 EVAL P I DECOMP JRIH WITH USIT TOOL ON SLB ELINE TO 2,992' MD , -MAKE LOGGING PASS FROM 2,992'MD TO 75' LOOKING FOR TOP OF CEMENT BEHIND THE 1 9-5/8"CASING SEND LOG DATA TO TOWN FOR REVIEW. 17:30 18:00 J 0.50 j EVAL P I DECOMP LD USIT LOGGING TOOLS 1 i I I - j-PREP ELINE FOR UPCOMING EZSV RUN. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 12 of 71 4,;. Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date.6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Dp Phase Description of Operations Date From-To Hrs Task Code NPT NPT Depth (hr) (usft) 18:00 - 21:00 3.00 DHB P DECOMP MAKE UP THE 9-5/8"HES EZ DRILL SVB SQUEEZE PACKER 1 PJSM FOR RIGGING UP EZ DRILL. i-ENSURE DIMENSIONS ARE CORRECT AND MEASURE OFFSETS FROM THE CCL TO THE EZSV j 1-RIH WITH EZSV ON E LINE. 4-MAKE TIE IN PASS TO PREVIOUS LOG RUN. I*WSL VERIFYING THE LOGS FOR 9-5/8"CUT DEPTHS AND EZSV SET DEPTHS -REVIEW WITH ONSITE GEO,DD AND TOWN ODE. -SET EZSV AT 2,820'MD 21 00 - 22:30 1.50 DHB P DECOMP POOH WITH EZSV RUNNING TOOL ON E LINE , -VERIFY CORRECT HOLE FILL ON THE TRIP i TANK , -LAY DOWN WIRELINE TOOLS FROM RIG 4 FLOOR MOVE SLB WIRELINE OUT OF THE CRITICAL PATH 22:30 - 23:30 1.00 DHB P DECOMP RIG UP TO TEST THE 9-5/8"EZSV ' -PJSM FOR PRESSURE TESTING-ENSURE 1 PROPER LINE UP FOR TESTS,DISCUSS HIGH PRESSURE AND MAINTAINING PROPER I ! "EXCLUSION ZONES FROM HIGH PRESSURE 1 ! i I-250 PSI LOW,3000 PSI HIGH,BOTH FOR 5 MIN-GOOD TESTS ,23:30 - 00:00 0.50 CLEAN 1 P DECOMP PU&MU BHA#3 FOR CASING CUTTING RUN. RU 8-1/4"MULTI STRING CUTTER,XO,8-1/2" STAB,XO TO DP. 4/29/2015 00:00 - 03:00 3.00 CLEAN 1 P DECOMP RIH WITH THE 8-1/4"MULTI STRING CUTTER I ;ASSEMBLY ON 4"DP SINGLES RIH TO 1,814'ON SINGLES FROM THE PIPE 1 SHED.-ENOUGH DP TO FINISH INTERMEDIATE SECTION I-CONT RIH FROM 1,814'MD TO-2,800'MD ON 4"DP STANDS FROM THE DERRICK -MONITOR TRIP ON TRIP TANK,OBSERVED CORRECT HOLE DISPLACEMENT DURING TRIP 03 00 - 04:30 1.50 CLEAN P DECOMP RIH AND TAG EZSV ON DEPTH AT 2,820'MD BY DRILL PIPE MEASUREMENT SET DOWN 5K TO VERIFY LOCATE COLLARS ABOVE AND BELOW AGREED CUT POINT AT 1,993' -PU TO 2,004'MD AND MU SINGLE TO LOCATE COLLAR AT 2,020'MD -30 SPM,WITH 180 PSI-LOCATED COLLAR AT 2,022 PU AND LOCATE UPPER COLLAR AT 1,990' WITH 30 SPM,180 PSI. PU SPACE OUT PUPS TO ENSURE FULL DP JOINT ACROSS THE STACK TO MAKE FINAL CUT AT 1,992' -MW-8.5 PPG IN/OUT Printed 7/6/2015 11.00.17AM •• North.America-ALASKA BP Page 13 of 71 4' n ,,, .,, . "V"*"', , Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time 11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 06:00 1.50 CUT P DECOMP !MAKE CUT IN THE 9-5/8"CASING AT 1,993'MD LOCATE 9-5/8"COLLARS TO IDENTIFY PROPER CUT DEPTH PJSM WITH RIG CREWAND BAKER REP I FOR MAKING CUT ESTABLISH PARAMETERS AND OBTAIN SPR5. '"PUW=93K, SOW=95K LOCATE LOWER COLLAR WITH KNIVES AT 2,322'-PUMPS ON AT 3 BPM,180 PSI RACK BACK ONE STAND -LOCATE UPPER COLLAR WITH KNIVES AT 1,980'-PUMPS ON AT 4 BPM,210 PSI -SET KNIVES AT 1,993'FOR CUT SPR'S AT 2,306'MD-MW 8.5 PPG -1)30SPM/80PSI,40SPM/140PSI -2)30 SPM/80 PSI,40 SPM/140 PSI 06:00 - 06:30 0.50 CUT P DECOMP CUT 9-5/8"47#BTC CASING AT 1,993'MD -STARTED PUMPS AT 252 GPM WITH 600 PSI, RPM=70 WITH 1-2K TORQUE '-OBSERVED PRESSURE DROP FROM 630 PSI TO 380 PSI,AND PRESSURE INCREASE ON -THE OA FROM 15 PSI TO 140 PSI CONTINUE CUTTING AT 6.6 BPM WITH 700 'PSI FOR 15 MINS AT 70 RPM W/1-5K TQ,AS PER WELL PROGRAM TO ENSURE GOOD CUT. 06:30 - 08:30 2.00 CLEAN P DECOMP RIG UP TO CIRCULATE OUT ARCTIC PACK FROM BEHIND 9-5/8"CASING -PJSM FOR CIRCULATING OUT FREEZE PROTECT-REVIEW PROCEDURE,DISCUSS CORRECT LINE UP AND PUMPING SCHEDULE.SPILL PREVENTION. R- IG UP LITTLE RED TO CHOKE MANIFOLD -TEST LINES TO 250 PSI LOW/3500 PSI HIGH -GOOD TEST -PUMP 2 BBLS OF 140 DEG DIESEL DOWN ITHE DRILL STRING AT 1.5 BPM,200 PSI, TAKING RETURNS BACK TO THE PITS. !-SHUT ANNULAR PREVENT ER AND PUMPED AN ADDITIONAL 78 BBLS OF 140 DEG DIESEL. I-PUMPED 25 BBLS OF 9.8 PPG BRINE DISPLACING A TOTAL OF 100 BBLS OF DIESEL INTO THE 13-3/8"BY 9-5/8"ANNULUS AT THE CUT AT 1,993'MD TAKING RETURNS OUT THE OA TO THE FLOW BACK TANK -2 BPM,WITH 1230 PSI. -ALLOW DIESEL TO SOAK IN THE 13-3/8"BY 9-5/8"ANNULUS FOR ONE HOUR. Printed 7/6/2015 11 00 17AM • North America-ALASKA-BP • Page 14 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site.PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual(g60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ' Phase Description of Operations 1 (hr) _ (usft) -x- 08:30 - 11:30 3.00 CLEAN 1 P DECOMP CIRCULATE OUT ARCTIC PAC FROM 13-3/8" BY 9-5/8"ANNULUS LINE UP RIG PUMPS TO CIRCULATE 9.8 PPG HEATED BRINE !-PUMP 235 BBLS OF 9.8 PPG BRINE 210 GPM, 660 PSI -50 BBLS OF DEEP CLEAN PILL,40 BBLS OF THIGH VIS SPACER, 1 -140 BBLS OF 8.5 SEAWATER,W/252 GPM, 1380 PSI,UNTIL RETURNS CLEAN UP I-SHUT DOWN PUMPING,BLOW DOWN I CHOKE MANIFOLD AND HARD LINES EMPTY THE FLOW BACK TANK IN PREPARATION TO PUMP DEEP CLEAN PILL. I-MONITOR WELL 10 MIN-WELLSTATIC 11:30 - 13:30 2.00 CLEAN P DECOMP POOH WITH 8-1/4"BAKER MULTI STRING CUTTER ASSEMBLY -LD 4"SINGLE AND TWO PUPS USED FOR SPACE OUT TO MAKE CUT -POOH FROM 1993'MD TO 11' -TRIP MONITORED ON TRIP TANK BY DRILLER AND PIT WATCHER-CORRECT HOLE FILL OBSERVED 13:30 - 16:00 2.50 CLEAN P DECOMP -CLEAN AND CLEAR RIG FLOOR -PREP FOR 9-5/8"CASING PULL 1-BRING CASING TONGS TO THE RIG FLOOR, RU CASING EQUIPMENT,ENSURE CORRECT XO'S ARE ON THE RIG FLOOR. -MAKE UP 9-5/8"BTC XO TO THE FOSV -PULL WEAR RING 16:00 - 18:30 2.50 CLEAN P DECOMP MAKE UP 9-5/8"CASING SPEAR ASSEMBLY ' -PJSM FOR MAKING UP THE 9-5/8"BOT I SPEAR ASSEMBLY.-DISCUSS MAX FACTOR FOR PULLING ON HANGER -DRAIN THE STACK j-RIH&ENGAGE SPEAR TO 9-5/8"CASING& 1 MANDREL HANGER,SET DOWN 10K TO ENGAGE SPEAR -CAMERON REP TO BOLDS HANGER PULLED FREE WITH 245K,PUW- 1 140 K ' CIRCULATE SURFACE TO SURFACE DUE TO WELL BEING OUT OF BALANCE WITH 630 GPM,110 PSI -LD SPEAR AND CROSS OVERS Printed 7/6/2015 11.00.17AM North America-ALASKA-Bp Page 15 of 71 f=. Operation Summary Report V Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. WWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth i Phase Description of Operations (hr) (usft) 18 30 - 00:00 5.50 CLEAN P DECOMP PULL AND LAY DOWN 9-5/8"47#,L-80 BTC CASING PJSM FOR LAYING DOWN CASING-REVIEW DDI PROCEDURE,DISCUSS HAZARDS, POSSIBLE BROKEN CENTRALIZER S -REVIEW WELL CONTROL FOR 9-5/8" I ACROSS THE STACK,ENSURE CORRECT LIFTING SUB IS MADE UP TO THE SAFETY JOINT.ENSURE CASING IS PROPERLY I CLEANED OFF PRIOR TO SENDING OUTSIDE. -PULL AND LD 9-5/8"JOINTS FROM 1,993'TO ,SURFACE -48 FULL JOINT 1)CUT JOINT=13.49',W/ 9-3/4"FLARE '-9-CENTRALIZER S WITH TWO OF THEM I ,MISSING LOWER PARTSAND PIECES OF BOW SPRING ABOUT 6 TOTAL PIECES I 'MISSING. PIPE IN GOOD CONDITION OVERALL- : I� i ` AVERAGE BREAK OUT-10K 4/30/2015 00:00 - 03:30 3.50 CLEAN P 1 DECOMP CLEAN AND CLEAR RIG FLOOR FROM PULLING 9-5/8"CASING -CLEAN OUT THE DRIP PAN OF REMAINING ARCTIC PACK. *SIM OPS MOBILIZE AND PREP CLEAN OUT I BHA. ' *FORKLIFT OPERATOR OBSERVED LEAK COMING FROM CELLAR.LEAK COMING FROM THE CELLAR BOX IDENTIFIED THE FLUID TO BE FRESH WATER I 1 -MADE NOTIFICATION TO 5700 NON I 'EMERGENCY SPILL LINE,ESTIMATED 1.5 BBL ,LEAKED OUTSIDE CELLAR. I NOTIFIED ROTARY SUPT&DS7-07 OPERATOR. Printed 7/6/2015 110017AM SNorth America-ALASKA BP Page 16 of 71 iF Operation Summary Report'' , Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project Prudhoe Bay r Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum 07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) (usft) - 03:30 - 08:30 5.00 CLEAN P 1,993.00 DECOMP !PICKED UP NECESSARY TOOLS FOR CLEAN OUT RUN PU PART OF BHA. -DECIDED TO DRAIN THE STACK AND !INSPECT THE BOP PRIOR TO RUNNING I CLEAN OUT -FOUND CENTRALIZER PIECES LODGED ACROSS THE STACK AT THE BLIND SHEARS SAND THE LOWER RAMS. I-REVIEW BP 10-65 AND CONFIRM PROPER BARRIERS IN PLACE FOR BREAKING CONTAINMENT -TESTED EZSV&STABLE FLUID COLUM i CONFIRM WITH ROTARY SUPT FOR PLAN !FORWARD TO REMOVE DEBRIS 1-OPEN LOWER RAM DOORS TO REMOVE 'DEBRIS PLACE PLYWOOD ACROSS OPENING -REMOVE CENTRALIZER DEBRIS FROM BLIND SHEAR CAVITY FROM SURFACE WITH MAGNET. '-FUNCTION THE BLIND RAMS AND FOUND ONE MORE PIECE -REMOVED TOTAL OF THREE PIECES FROM .THE STACK. SIM OPS-LOADING 9-5/8"CASING AND INSTALLING CENTRALIZERS 08:30 - 12.00 3.50 BOPSUR N SFAL 1,993.00 DECOMP PRESSURE TEST LOWER RAM CAVITY DOOR. PJSM FOR PRESSURE TESTING-REVIEW PRESSURE CROSS CHECK LIST FOR I CORRECT LINE UP AND PRESSURE HAZARDS AND MITIGATION'S INSTALL TEST PLUG WITH 4"TEST JOINT PRESSURE TEST DOOR SEALS 250 LOW, 3500 PSI HIGH FOR 5 CHARTED MIN-WITH !ANNULAR PREVENTER CLOSED ON TEST JOINT LOW PRESSURE TEST PASSED OBSERVED LEAK FROM CONTROL LINE PORTS DURING THE HIGH PRESSURE TEST.- OPENED ANNULAR PREVENTER AND DRAINED STACK. CAMERON REP REMOVED AND INSTALLED NEW PLUGS FOR TEST -RE-TEST TO 3500 PSI HIGH FOR 5 MIN CHARTED-GOOD TEST *LEAK IN TEST PORTS NOT OBSERVED DURING PRIOR TESTS DUE TO CASING PACK OFF COVERING PORTS. **SIM OPS-L2RA BEING CONDUCTED FOR NECESSARY WELDING ON HYDRAULIC LINES UNDER THE RIG FLOOR WITHIN 35'OF THE WELL BORE. -BP WSL,BP ROTARY SUPT,BP SAFETY,DDI SUPT,DDI TOOL PUSHER,DDI SAFETY,DDI RIG WELDER Printed 7/6/2015 11 00.17AM 411 North America-ALASKA-BP • Page 17 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date I From-To Hrs Task I Code I NPT NPT Depth Phase I Description of Operations (hr)_ (usft) '12:00 - 16:00 4.00 CLEAN j N RREP 1,993.00 DECOMP CODE 8 RIG DOWN TIME- L2RAAPPROVED FROM BP ANCHORAGE LEADERSHIP- ROTARY TL &WELLS /MANAGER I-PROCEED WITH BLOW DOWN AND NITROGEN PURGE OF HYDRAULIC LINES. -PJSM WITH ALL PERSONAL INVOLVED TO I iDISCUSS HAZARDS AND MITIGATION S FOR L2RA AND HOT WORK PERMIT MAKE WELDING REPAIR AND TEST. -REPAIR !LOOKS GOOD 16:00 - 20:00 4.00 CLEAN P • DECOMP ;MAKE UP THE 9-5/8"DRESS OFF ASSEMBLY 'BHA TO 233' -PJSM FOR MAKING UP BHA.-DISCUSS NON SHEARABLES ACROSS THE STACK I I-PULL AND RIG DOWN THE TEST PLUG FROM THE WELLBORE AND LD TEST JOINT I RIH WITH DRESS OFF ASSEMBLY ON 4"DP ! STAND FROM THE DERRICK RIH FROM 233'TO 1942'MD 20:00 - 21:00 1.00 CLEAN P 'DECOMP ,WASH 12-1/8"DRESS OFF MILL OVER CASING ISTUB AT 1,993'MD -OBTAIN PARAMETERS AND SPR'S. I -PUW-93K,SOW-95K,ROT-95K I I -210 GPM,100 PSI,55 RPM,1-2K TQ I-MW-8.5 PPG SEAWATER IN/OUT i-WORK DRESS OFF MILL OVER 9-5/8" i CASING STUB WITH NO ROTATION TO -_ l VERIFY GOOD DRESS OFF. 21:00 - 22:30 1.50 CLEAN P DECOMP ! CIRCULATE BOTTOM UP X 2 PUMP 30 BBL HIGH VIS SWEEP AFTER FIRST ' I BOTTOMS UP I-BOTTOMS UP WITH SWEEP SHOWED MINIMAL AMOUNTS OF ARCTIC PAC-DIVERT I RETURNS TO ROCK WASHER ' -630 GPM,750 PSI MW-8.5 PPG SEAWATER IN/OUT 22:30 - 00:00 1.50 CLEAN P DECOMP POOH WITH 9-5/8" DRESS OFF ASSEMBLY ON 4"DP I I PJSM FOR PULLING PIPE-REVIEW NON SHEARABLES ACROSS THE STACK -MONITOR WELL PRIOR TO PULLING OFF BOTTOM-WELL STATIC POOH FROM 1993'MD TO 328'MD -MONITOR WELL PRIOR TO PULLING BHA THROUGH THE STACK-WELL STATIC. -PULL AND LD BHA ' -MONITOR TRIP ON TRIP TANK-OBSERVED WELL TAKING CORRECT HOLE FILL- VERIFIED TRIP SHEET ACCURACY 5/1/2015 00:00 - 01:00 .' 1.00 CLEAN I P DECOMP 'LAY DOWN BHA -FLOW CHECK PRIOR TO PULLING NON-SHEARABLES ACROSS STACK TABLE TOP KICK DRILL WHILE NON-SHEARABLES ACROSS STACK VERIFY INNER MILL FOR WEAR INDICATING PROPER DRESS OFF Printed 7/6/2015 11:00:17AM North America-ALASKA-BP Page 18 of 71 „ 41111 Operation Summary Report ' Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum.07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) I 01:00 03 00 I 2.00 CLEAN P t DECOMP CLEAN AND CLEAR RIG FLOOR OF ALL BHA ICOMPONENTS -PREP RIG FLOOR FOR RUNNING CASING MU CROSS OVERS AND BRING BAIL EXTENSIONS AND CEMENT HEAD -MOBILIZE PUPS NEEDED FOR RUN PJSM FOR 9-5/8"CASING PATCH TIE BACK PJSM HELD WITH BAKER FISHING,BAKER COMPLETION,DOYON CASING,HES COMPLETION,AND RIG CREW. -DISCUSS UPCOMING CASING PATCH TIE BACK.,3RD PARTY REPS ON LOCATION,THE I IMPORTANCE OF TRACKING FLUIDS, I NON-SHEARBLES ACROSS STACK REVIEWED DDI PROCEDURE FOR RUNNING TIE BACK-STRESSED THE HIGH RISK OF USING THE OVER SIZED CASING TONGS VERIFIED 9-5/8"CASING PIPE COUNT WITH DRILLER,WSL,BAKER REPS,HALLIBURTON REPS,AND TOUR PUSHER -REVIEWED TALLY FOR ACCURACY AND RUNNING ORDER. 03:00 - 11:00 8.00 CASING P DECOMP RUN 9-5/8",47#,L-80 VT CASING AND BOWEN PATCH F/SURFACE T/1993'MD. -DRILLER AND LEAD FLOOR HAND VERIFY CORRECT LIFTING EQUIPMENT SIZE AND RATING. -PU BOWEN PATCH,AND ECP ASSEMBLY. VERIFY CORRECT SHEAR SCREW NUMBER AND RATING OF ECP,PER BAKER REP. -ALL CONNECTIONS BELOW ES-CEMENTER BAKER-LOC'D. -USE JET-LUBE SEAL GUARD THREAD COMPOUND. -TORQUE TURN CONNECTIONS TO 15,900 FT-LBS. -RUN 1 FREE FLOATING CENTRALIZER PER JT ON JTS 1-44 -OBTAIN PARAMETERS PRIOR TO SETTING DOWN ON STUB AT 1,915'MD PU 135K,SO 134K. -SET BOWEN PATCH OVER STUMP WITH 25K DOWN,PU&SET GRAPPLE W/25K OVER- PER BAKER REP. -PULL 100K OVER TO VERIFY PATCH ENGAGED. -SET CASING IN SLIPS AND MAKE UP CEMENT HEAD&BAIL EXTENSIONS WITH 50 K OVER -PICK UP 100K OVER STRING WEIGHT& PULL ROTARY SLIPS AND SET BRAKE FOR CEMENT JOB. Printed 7/6/2015 11'00:17AM • North America-ALASKA-BP • Page 19 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UW:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date % From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 12:00 1.00 CASING P DECOMP PRESSURE TEST CASING PATCH AND ECP -HOLD PJSM AND REVIEW PRESSURE CROSSCHECK LIST. -FILL LINES AND CHECK FOR LEAKS. -PRESSURE TEST INSIDE CASING TO 250 PSI 1 LOW FOR 5 MIN& 1000 HIGH PSI FOR 5 MIN, TEST GOOD. '--INCREASE PRESSURE IN 250 PSI INCREMENTS TO 1815 PSI,OPEN ECP INFLATION CONTROL VALVE,OBSERVE PSI DROP OF 165 PSI AS ECP INFLATES.-0.3 i BBLS TO INFLATE 1 , -INCREASE PRESSURE TO 2000 PSI,CLOSE ECP INFLATION CONTROL VALVE AND HOLD FOR 10 MINUTES,TO ENSURE VALVE CLOSED. -BLEED PRESSURE TO 0 PSI. OPEN ES-CEMENTER PRESSURE TO 2950 PSI,OBSERVE IES-CEMENTER SHEAR OPEN. 12:00 - 13:30 1.50 CASING P DECOMP I CIRCULATE CIRCULATE 300 BBL,120°F,8.5 PPG SEAWATER,210 GPM,90 PSI,100% RETURNS. MW-8.5 PPG SEAWATER IN/OUT Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 20 of 71 Operation Summary Report Common Well Name.07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:OOAM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual t60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 15:30 1 2.00 CASING P DECOMP CEMENT 9-5/8"CASING AS FOLLOWS -PUMP 10 BBLS OF 8.5 PPG OF SEAWATER FOR PT PRESSURE TEST SLB LINES AND RIG 1 I CEMENT LINES,250 PSI/4000 PSI,5 MIN/5 MIN,TEST GOOD. WSL VERIFY TRIP SETS FOR OVER PRESS 'SYSTEM j -SHUT IN ANNULAR PREVENTER AND OPEN OA VALVE TO FLOW BACK TANK.ENSURE i CORRECT LINE UP. 1-PUMP 165 BBLS OF 15.80 PPG CLASS G TAIL CEMENT @ 5.0 BPM,YIELD 1.17 CU.FT/SK. 1-DROP CLOSING PLUG. '-SLB KICK OUT PLUG WITH 10 BBLS OF SEAWATER WATER -PERFORM DISPLACEMENT WITH RIG AND 8.60 PPG SEAWATER PER SLB CADE. -CAUGHT CEMENT WITH 38 BBLS ' DISPLACED AT 5.0 BPM:W/100 PSI 100% RETURN FLOW - I,-MP#1 CHARGE PUMP LINE BEGAN LEAKING,SWITCHED TO MP#2 AND BEGAN PUMPING-MP#2 STROKE COUNTER NOT I WORKING PROPERLY.SHUT DOWN AND LINED UP SLB TO FINISH THE ;DISPLACEMENT. -SLB PUMPED 85 BBLS OF SEAWATER DISPLACEMENT AT 5 BPM,ICP-423 PSI, ' FCP-1300 PSI -REDUCED RATE TO 2 BPM -PUMPED 8 BBLS OF SEAWATER DISPLACEMENT AT 2 BPM,ICP-780 PSI,FCP I-867 PSI -BUMP PLUG AT 143 BBLS TOTAL DISPLACED AND INCREASE PRESSURE TO 2500 PSI, OBSERVE ES CEMENTER CLOSE. -BLEED PRESSURE OFF AND CHECK FOR FLOW.ZERO FLOW OBSERVED FOR 10 MINUTES -TOTAL DISPLACEMENT VOLUME 143 BBLS -CEMENT RETURNS AT SURFACE AT 90 BBLS DISPLACED,ESTIMATED 53 BBLS OF 1 CEMENT TO SURFACE. -RETURNS FOR ENTIRE JOB TAKEN BACK TO , THE FLOW BACK TANK. -O LOSSES DURING CEMENT JOB. 1 -CEMENT IN PLACE AT 15:25 HRS. 15:30 - 16'30 1.00 CASING P ! 1 DECOMP FLUSH OUT STACK TO CLEAN UP CEMENT I I -PUMP 60 BBL BLACKWATER PILL DOWN KILL I LINE AND OUT TO FLOWBACK TANK AT 133 GPM W/60PSI TO CLEAN RESIDUAL CEMENT OUT OF STACK&LINES TO FLOW BACK TANK FOLLOW WITH 20 BBL SEAWATER TO FLUSH OUT BLACKWATER PILL CONFIRM 0 PSI BELOW ANNULAR AND OPEN ANNULAR Printed 7/6/2015 11:00:17AM • North America-ALASKA-SP III Page 21 of 71 Operation Summary Report` Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 116:30 - 19:00 2.50 BOPSUR P DECOMP RIG DOWN CEMENTING EQUIPMENT -RIG DOWN CEMENT HEAD CROSSOVER -SUCK OUT THE CASING FOR CASING CUT -BLOW DOWN CHOKE,KILL,AND HOLE FILL LINES -DRAIN THE STACK- NIPPLE DOWN BOPE -PJSM FOR N/D BOPE.FOCUSED ON OVERHEAD LOADS AND PROPER COMMUNICATION WHEN LIFTING STACK. I-SPLIT STACK BELOW TUBING SPOOL AND LIFT STACK OFF WELLHEAD. LAY DOWN HALLIBURTON CEMENT HEAD **SENT NOTIFICATION TOAOGCC FOR UPCOMING BOPE TEST`* 19:00 - 22:00 3.00 WHSUR P DECOMP SET EMERGENCY SLIPS AND CUT 9-5/8" CASING -PJSM WITH CAMERON CONCERNING COMMUNICATION WHILE LIFTING STACK AND MAKING SURE BOP HOISTS ARE LOCKED OUT PRIOR TO INSTALLING SLIPS. WITH 100K OVER STRING WEIGHT PULLED 'ON CASING,CIW INSTALL EMERGENCY I ! SLIPS. -SET DOWN 100K PER CIW REP. I-INSTALL WACHS CUTTER AND CUT 9-5/8" CASING. -PULL 9-5/8"CUT JOINT TO FLOOR AND LD IN PIPE SHED. -RD WACHS CUTTER AND PREP TO SET STACK BACK ON WELLHEAD. 22:00 - 00.00 2.00 WHSUR P DECOMP REMOVE TUBING SPOOL -SET BOP STACK BACK ON WELLHEAD. -NIPPLE DOWN EXISTING TUBING SPOOL FROM BOP AND SET BOP STACK BACK ON STUMP. -REMOVE EXISTING TUBING SPOOL FROM WELLHEAD. CAMERON REP-INSTALLING PACK OFF ABOVE SLIPS. 5/2/2015 00.00 - 03.00 3.00 WHSUR P DECOMP INSTALL 9-5/8"PACK OFF -CAMERON REP TO INSTALL PACK OFF AND TEST -UNABLE TO INSTALL BASE RING FOR PACK OFF -DISCOVERED THE 9-5/8"CASING NOT CENTERED IN THE WELL HEAD.DUE TO SLIPS NOT BEING LEVEL -CAMERON REP DISCUSSING POSSIBLE PLAN FORWARD WITH CAMERON LEADERSHIP IN ANCHORAGE -CONTACT BP ODE IN ANCHORAGE AND FIELD ROTARY SUPT AND DISCUSS PLAN FORWARD Printed 7/6/2015 11 00.17AM y,,` • North America-ALASKA-BP I Page 22,°f 71 Operation Summary Report , ; Common Well Name:07-07A AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) + (usft) 03:00 15:00 12.00 WHSUR N SFAL DECOMP I DECISION MADE TO SPEAR THE CASING ATTEMPT TO PU ON CASING AND LEVEL THE SLIPS -PJSM FOR OUT OF SCOPE OPERATIONS -DISCUSS HAZARDS FOR PICKING UP • I SPEAR.DISCUSS MAX OVER PULL AND REVIEW WEAK POINT IN THE LIFTING •OPERATION.-DISCUSS PROPER EXCLUSION ZONES FOR OVERHEAD WORK. -PU/MU 9-5/8"SPEAR TO JOINT OF DP RIH AND ENGAGE THE 9-5/8" -PULL TO 300K-166K OVER STRING WT WHEN SET. -CAMERON REPS WORKING ON ADJUSTING THE SLIP DIES TO BETTER CENTER PIPE. -RE-EVALUATE ISSUE WITH CIW MANAGER IN ANCHORAGE AND ON SITE REP I-DECISION MADE FROM THE CIW SERVICE MANAGER TO MODIFY THE INSIDE OF THE ENERGIZING RINGS TO FIT THE CASING HEAD PROFILE. I-SENT THE RINGS TO BAKER OIL TOOLS FOR MODIFICATION.MACHINIST TOOK A TOTAL I.1/8"OFF THE ENERGIZING RINGS TO HELP BETTER CENTER THEM ON THE PIPE. HE I TOOK 1/8"OFF THE HEIGHT OF THE PLATE TO HELP ACCOMMODATE SECONDARY SEAL BETTER. -RETURNED WITH MACHINED RINGS AND INSTALLED THEM IN THE WELLHEAD. -ENERGIZED THE PRIMARY PACK OFF WITH 600 FT/LB OF TORQUE.OBSERVED A GOOD SEAL IN CONTACT WITH THE CASING. • -INSTALLED THE NEW TUBING SPOOL AND TORE THE SECONDARY SEAL IN THE • PROCESS,REMOVED THE SPOOL REPLACED • THE SEALAND REINSTALLED NEW SPOOL. � I � "SIM OPS-WORKING ON#1 MUD PUMP • CHARGE PUMP LINE. - LOAD PIPE SHED WITH MWD TOOLS TO GET READY FOR UPCOMING DRILL OUT • RIG PERFORMING WORK ORDERS 15:00 21:00 I 6.00 BOPSUR P i DECOMP NU 13-5/8"5K BOP STACK -ANNULAR PREVENTER -UPPER RAMS WITH 7"SOLID BODY RAMS BLIND SHEAR RAMS • -MUD CROSS -LOWER RAMS WITH 3-1/2"X 6"VBR'S •PJSM FOR NU OPERATIONS.-REVIEW DDI PROCEDURE -MAKE UP THE STACK TO THE TUBING SPOOL,MU RISER,FLOW LINE,HOLE FILL LINE AIR BOOTS AND KILL LINE -TIGHTEN TURN BUCKLES AND ADJUST STACK. • -TORQUE ALL NUTS TO CORRECT SPEC OF 1800 FT/LB CHANGE OUT THE UPPER RAMS FROM THE 9-5/8"FIXED BORE RAMS TO THE 7"FBR'S. Printed 7/6/2015 11:00 17AM • North America-ALASKA-BP • Page 23 of 71 , ,, Operation Summary Report I Common Well Name.07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:OOAM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 21:00 - 22:00 1.00 BOPSUR P DECOMP SHELL TEST THE BOP STACK PRESSURE TEST THE 7"RAMS,BREAK AT THE SPOOL AND THE OUTER PIGGY BACK 1 VALVE ON THE TUBING SPOOL. 250 LOW/3500 PSI HIGH FOR 5 CHARTED MIN-GOOD TEST 22:00 - 00 00 2.00 WHSUR P DECOMP PRESSURE TEST THE 9-5/8"CASING PACK OFF. -CIW TO INJECT PLASTIC PACKING IN THE ENERGIZED SEALS -PRESSURE TEST TO 250 LOW FOR 5 MIN, 13500 PSI FOR 30 MIN-CHARTED,GOOD PASSING TEST 5/3/2015 00:00 - 01 30 1.50 WHSUR P DECOMP COMPLETED THE 9-5/8"CASING PACK OFF PRESSURE TESTING '-PLY 5"ELEVATORS -MU SAFETY JOINT WITH TIW, I-FLUID PACK AND HYDRO TEST THE REPAIRS MADE TO THE CHARGE PUMP LINE ON MP#2 INSTALL WEAR RING WITH 9-1/4"ID-VERIFY CORRECT LDS MEASUREMENT 01:30 - 04:30 3.00 CLEAN P DECOMP MAKE UP 9-5/8"CLEAN OUT BHAAS DIRECTED BY BOT REP -PJSM FOR M/U 9-5/8"CLEANOUT BHA- DISCUSS PLAN FOR NON-SHEARABLES I ACROSS STACK AND FLUID TRACKING WHILE RIH.REVIEW DDI PROCEDURE.DISCUSS CORRECT LIFTING EQUIPMENT NEEDS FOR PICKING UP BHA -MU CLEAN OUT BHA PER THE DRILLING PROGRAM DIRECTION MU BHA TO-800' 04:30 - 05:00 0.50 CLEAN P DECOMP RIH W/9-5/8"CLEAN OUT BHA RIH ON ELEVATORS F/-800'T/1,800'MD OBTAIN PARAMETERS ABOVE ES CEMENTER ,CEMENT PUW-109K,SOW-109K SPR'S TAKEN MONITOR TRIP ON TRIP TANK-CORRECT DISPLACEMENT OBSERVED -MW-8.5 PPG IN/OUT D1-DRILL PERFORMED *D1 DRILL-CREW RESPONSE TIME 1:45 -AAR DRILL CONDUCTED-DISCUSSED THE NEED FOR CALLING THE WSL LEADER TO NOTIFY OF SIMULATED SHUT IN. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 24 of 71 Operation Summary Report Common Well Name 07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig-Contractor:DOYON DRILLING INC. I UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase 1 Description of Operations (hr) ' (usft) 05:00 - 08:30 3.50 CLEAN P DECOMP DRILL OUT 9-5/8"CASING PATCH ES CEMENTER AND CLOSING PLUG OBTAIN PARAMETERS AND SPRSAT 1,840' MD PU 109K,SO 109K ROT 100K TAG CEMENT STRINGERS AT 1,911',WASH 1&REAM DOWN TO 1,948'MD '-510 GPM,840 PSI,80 RPM,2K TQ TAG HARD CEMENT AT 1,948'MD -MILL CLOSING PLUG AND ES CEMENTER F/ 1949'MD TO 1,952'MD 1-420 GPM,610 PSI,60-80 RPM WITH 3-4K I TQ, 5-7K WOB, 1 PUMP HIGH VIS SWEEP AT SAME PARAMETERS I ,-OBSERVED ALUMINUM&CEMENT AT ' I i BOTTOMS UP -MW-8.5 PPG IN'/OUT 08:30 - 14:30 6.00 CLEAN P DECOMP 1 REAM DOWN WITH 8-1/2"CLEAN OUT BHA F/ 1,951'TO 2790' -WASH&REAM DOWN F/1,951'TO 2,790' W/ 510 GPM,900 PSI,80 RPM 1 '-WASH DOWN FROM 2,790'MD AT 84 GPM, f'TAG UP A 2,817'MD WITH 5K DOWN. OBSERVE WHAT APPEARS TO BE DEBRIS ON TOP OF THE EZSV,PU PIPE AND ROTATE PIPE,SET BACK DOWN WITH 20K.PICK BACK i UP AND SET DOWN WITH 5K AND TO 2,819'. RACK BACK ONE STAND AND CIRCULATE BOTTOMS X 2 UP WITH HIGH VIS SWEEP -420 GPM,690 PSI,WITH 90 RPM, RECIPROCATE PIPE ONE FULL STAND OBTAIN PARAMETERS AND SPR'S -PUW-124K,SOW-118K -SMALL AMOUNTS OF ALUMINUM DEBRIS AND CEMENT RETURNED WITH SWEEP. -MW-8.5 PPG IN/OUT 14:30 - 17:30 3.00 CLEAN P DECOMP POOH WITH 8-1/2"CLEAN OUT BHA ON ELEVATORS ' -MONITOR WELL 10 MIN PRIOR TO PULLING OFF BOTTOM-WELL STATIC , -POOH FROM-2,730'MD TO-800' -MONITOR WELL PRIOR TO PULLING THE BHA THROUGH THE STACK-WELL STATIC -DID NOT OBSERVE ANY TIGHT SPOTS OR OVERPULL GOING THROUGH THE ES CEMENTER&CLOSING PLUG DEPTHS. -MONITOR TRIP ON TRIP TANK-OBSERVED CORRECT HOLE FILL -LAY DOWN BHAAS DIRECTED BY BAKER REP-STAND BACK 5"HWDP FOR NEXT BHA � -CLEAN OUT BOOT BASKETS-BASKETS FILLED CEMENT AND ALUMINUM DEBRIS. 17:30 - 18:00 0.50 CLEAN 1 P DECOMP 1CLEAN AND CLEAR RIG FLOOR 1 -RIG SERVICE,SERVICE TOP DRIVE Printed 7/6/2015 11:00:17AM North America-ALASKA-BP • Page 25 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date 6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual i60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 20:00 2.00 TCLEAN P DECOMP RINSE BOPE STACK -PJSM FOR RINSING STACK-REVIEW DDI PROCEDURE !-MU STACK WASHER TO SINGLE AND RUN INSIDE THE STACK -RINSE ONCE AND OPEN MANUAL CHOKE AND KILL LINE VALVES AND RINSE AGAIN. �-PULL AND LD STACK WASHER BLOW DOWN i I , TOP DRIVE, I l -PULL WEAR RING -RIG UP TEST EQUIPMENT FOR THE CASING TEST 20:00 - 22:00 2.00 CASING P DECOMP !PRESSURE TEST 9-5/8"CASING PJSM FOR PRESSURE TESTING-ENSURE CORRECT LINE UP,AND DISCUSS CHECKLIST FOR HAZARDS ASSOCIATED WITH HIGH PRESSURES. -250 PSI LOW FOR 5 MIN/3500 PSI FOR 30 MIN-CHARTED LOST 20 PSI'FOR ENTIRE HIGH PRESSURE TEST. PUMPED 3.4 BBLS AND GOT 3.25 BBLS BACK RECEIVED AUTHORIZATION TO PROCEED j-FROM RICH BURNETT WEEKEND TEAM LEAD. 22:00 - 00:00 2.00 BOPSUR P DECOMP j PRESSURE TEST 13-5/8"5K BOPE -TEST BOPE TO 250 LOW,3500 PSI HIGH IFOR 5MIN EACH TEST WITH 4"&7"TEST JOINTS -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS TEST WITNESS WAIVED BY AOGCC REP CHUCK SCHEVE VIA EMAIL ON 5/3/15 BOPE CONFIGURATION: -ANNULAR PREVENTER -UPPER RAMS WITH 7"FIXED BORE RAMS -BLIND SHEAR RAMS -MUD CROSS LOWER RAMS WITH 3-1/2"X 6"VBR'S 5/4/2015 00:00 - 04:00 4.00 BOPSUR P DECOMP 'PRESSURE TEST 13-5/8"5K BOPE -TEST BOPE TO 250 LOW,3500 PSI HIGH FOR 5 MIN EACH TEST WITH 4"&7"TEST JOINTS -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS TEST WITNESS WAIVED BYAOGCC REP CHUCK SCHEVE VIA EMAIL ON 5/3/15 04:00 - 06:00 2.00 BOPSUR P DECOMP CLEAN&CLEAR RIG FLOOR-RIG DOWN TESTING EQUIPMENT -BREAK DOWN THE TUBULAR S FOR TESTING AND SEND OUT OF PIPE SHED. -BLOW DOWN TOP DRIVE, CHOKE AND KILL LINE. -BOLDS AND PULL TEST PLUG- ' I -INSTALL WEAR RING. Printed 7/6/2015 1100:17AM • North America-ALASKA-BP 0 Page 26 of 71 a FA V Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay ' Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT 1 NPT Depth 1 Phase Description of Operations — —- 06:00 - 13:30 7.50 STWHIP P - (usft) WEXIT 'M/U WHIPSTOCK ASSEMBLY BHA#1 -9 5/8"BOTTOM TRIP,ANCHOR,9 5/8" WHIPSTOCK,8 1/2"WINDOW MILL,8 3/8" LOWER WINDOW MILL,(2)8 1/2"UPPER I MILLS,1 JT 5"HWDP,FLOAT SUB,MWD,XO 1 SUB,(6)6 1/4"DC,XO SUB,(18)JTS 5"HWDP. OAL OF BHA 856'MD. 1 i PERFORM SHALLOW HOLE TEST OF MWD 11688'MD. I500 GPM,810 PSI. 13:30 - 14:30 1.00 STWHIP P I WEXIT !RIH ON ELEVATORS FROM 854'MD TO 2,817' MD I -RIH ON ELEVATORS WITH 4"DP FROM DERRICK. -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT. ORIENTATE WHIPSTOCK TO 54 DEG RIGHT 1 i OF HIGH SIDE. -PUMP 480 GPM,900 PSI SET WHIPSTOCK AT 2,817'MD -SHEAR ANCHOR AT 20K,P/U TO VERIFY 'ANCHOR SET WITH 20K OVERPULL. '-SHEAR MILLING ASSEMBLY AT 47K,P/U TO I 1 VERIFY MILLING ASSEMBLY FREE. '-P/U BEFORE SHEAR=125K,P/U AFTER SHEAR=123K. 14 30 - 16:00 1.50 STWHIP P 1 WEXIT DISPLACE 8.5 PPG BRINE WITH 9.0 PPG LSND PJSM FOR DISPLACING OPERATIONS -DISPLACE PITS OF SEAWATER AND FILL WITH 9.0 LSND MUD -PUMP 25 BBL HI VIS SPACER. -15 BPM,920 PSI. j -OBTAIN SPRS. STAND BACK ONE STAND AND P/U A SINGLE : i [FOR SPACE OUT FOR MILLING OPERATIONS Printed 7/6/2015 11:00:17AM 110 North America-ALASKA-BP • Page 27 of 71 Operation Summary Report r. , r Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 23:30 7.50 STWHIP P WEXIT MILL WINDOW -TAG TOWAT2,795' -MILL 9 5/8"CASING FROM 2,795'MD TO BOW AT 2,812'MD. 1-TIME DRILL FIRST 1 FT 30 MIN -20 MIN/FT FOR EACH ADDITIONAL FT -80 RPM,5-9K TORQUE. 11 BPM,720 PSI I- 1K WOB FOR FIRST 3'THEN 4K TO 10K WITH LOWER MILL PASSING THROUGH, ITHEN BACK TO 1K TO 2K WHEN FIRST FULL I GAUGE MILL ENTERING WINDOWAND FINISH MILLING WITH ANYWHERE F/1K TO 10K WOB. '-DRILL 21'OF NEW FORMATION TO 2,833'MD 1-100 RPM,2-4K TORQUE '-525 GPM,1130 PSI -P/U=125K,S/O=125K,ROT=125 K WORK MILL THRU WINDOW WITH ROTATION AND PUMPS 2X'S II '-WORK MILL THRU WINDOW WITHOUT ROTARY '-WORK MILL THRU WINDOW WITHOUT ROTARY AND PUMPS AND SAW 2K DRAG ITHRU WINDOW F 11-CEMENT OBSERVED AT SHAKERS WHILE MILLING WINDOW -TOW 2,795'MD. MOW 2,803.5'MD. -BOW2,812'MD. 23'30 - 00:00 0.50 STWHtP P � WEXIT ,PUMP 30 BBL HI-VIS SWEEP. I 1 -PUMP 30 BBL SUPER SWEEP WHILE WORKING STRING INSIDE WINDOW F/2,752' I T/2,787'AT 11 BPM WITH 800 PSI. 5/5/2015 00:00 - 01:30 1 1.50 STWHIP P i WEXIT CONTINUE CIRCULATING WELL CLEAN IN PREPARATION FOR LOT. CONTINUE CIRCULATING WHILE WORKING 1 I 'STRING INSIDE WINDOW FROM 2,752'TO 2,787'AT 11 BPM WITH 800 PSI. i-CONFIRMED 9.0 IN AND OUT. -SHUT OFF PUMPS AND FLOW CHECK.NO FLOW OBSERVED. OBTAIN SLOW PUMP RATES. T BLOW DOWN TOP DRIVE. Printed 7/6/2015 11:00:17AM 4111/ North America-ALASKA-BP • Page 28 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To I Hrs TaskCode NPT NPT Depth p Phase �� Description of Operations (hr) (usft) - 01 30 - 03:30 2.00 STWHIP P WEXIT PERFORM LOT. -PJSM AND REVIEW DDI SOP. -RIG UP HEAD PIN CHART RECORDER AND DIGITAL GAUGE. I-PURGE KILL LINE AND PUMP LINES. CLOSE ANNULAR PREVENTER. PERFORM LOT AS PER BP SOP. 1.6 BBLS PUMPED WITH LEAK OFF PRESSURE OF 320 PSI.AT 9-5/8"WINDOW 2,812'MD,2,809'TVD.MW 9.0 PPG. -DISCUSSED RESULTS OF 11.19 PPG EMW LOT WITH ODE FOR APPROVAL TO PROCEED. 1-ODE DISCUSS RESULTS WITH WTL AND INFORM RIG TEAM T O PROCEED. I-BLEED PRESSURE OFF.TOTAL OF.5 BBL BLED BACK TO TRIP TANK -CHECK FOR PRESSURE AND OPEN ANNULAR PREVENTER. -R/D ALL TESTING EQUIPMENT AND BLOW DOWN KILL LINE. 03:30 - 04:30 1.00 STWHIP P WEXIT 'POOH WITH MILLING ASSEMBLY. -PJSM AND REVIEW DDI SOP. --FLOW CHECK WELL FOR TEN MINUTES WITH NO FLOW OBSERVED. POOH STANDING BACK 4"XT39 DRILL PIPE F/2,752'T/856'. -MONITOR WELL BEFORE PULLING i II NON-SHEARABLE BHA INTO BOPE STACK NO FLOW OBSERVED. 04:30 - 08.00 3.50 STWHIP P WEXIT LAY DOWN MILLING BHA. -PJSM AND REVIEW DDI SOP OF BHA. -STAND BACK NEEDED 5"HWDP AND UD 6-1/4"DRILL COLLARS. BREAK OUT AND UD MILL ASSEMBLY AND GAUGE MILLS. 08:00 - 09:30 ' 1.50 I STWHIP P WEXIT P/U STACK WASHER TO WASH STACK DUE TO MILLING OPERATIONS -FLUSH STACK AT 630 GPM. DRAIN STACK AND FUNCTION RAMS AND ANNULAR. REPEAT FLUSHING STACK AGAIN L/D STACK WASHER AND JOINT -BLOW DOWN TOP DRIVE 09:30 - 13:30 4.00 STWHIP P WEXIT M/U 8.5"INTERMEDIATE DRILLING BHA#1- WITH MUD MOTOR-FROM SURFACE TO 844' MD. PJSM DISCUSS WELL CONTROL DURING BHA M/U -8.5"GFI23 PDC,675M7850XP PDM 1.5 DEG MUD MOTOR,8-3/8"NM STABILIZER,XO SUB, PERISCOPE 675 LWD,TELESCOPE 675 MWD, 8 3/8"NM STABILIZER,(3)NM FLEX COLLARS, NM FLEX COLLAR(X3),FLOAT SUB,(13 JTS) 5"HWDP,HYDRAULIC JARS,(5 JTS)5"HWDP -MONITOR HOLE ON TRIP TANK-STATIC Printed 7/6/2015 11:00 17AM • North America-ALASKA-BP Page 29 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 14:30 + 1.00 STWHIP P WEXIT RIH ON ELEVATORS FROM 844'MD TO 2,742' MD 1-CHANGE OUT 5"ELEVATORS AND INSTALL !4"AIR SLIPS -RIH ON ELEVATORS WITH 4"DP FROM i DERRICK. -MONITOR WELL VIA TRIP TANK PROPER rDISPLACEMENT. SHALLOW HOLE TEST MWD:GOOD TEST 114:30 - 15:00 0.50 STWHIP ] P j WEXIT LUBRICATE RIG TOP DRIVE AND INSPECT BLOCKS 15:00 15:30 0.50 STWHIP P WEXIT [WASH DOWN FROM 2,742'MD TO 2,833'MD -DID NOT SEE ANYTHING PASSING THROUGH WINDOW TAGGED BOTTOM AT 2,833'MD OBTAIN SLOW PUMP RATES:MW 9.0 PPG IN/OUT ESTABLISH ECD BASELINE 15:30 - 22:00 6.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 2,833'MD TO 3,170'MD(3,149'TVD) -450 GPM,1,010 PSI ON,940 PSI OFF. -8K WOB,40 RPM,2K TORQUE ON,2K TORQUE OFF. P/U 125K,S/O 121K,ROT 123K. -ECD:ACTUAL= 9.82 PPG,CALC=9.4 PPG. SURVEY EVERY-30 FT. -MUD WEIGHT:LSND 9.0 PPG IN,9.0 PPG OUT. *FLUID LOSS FOR DAY=0 BBLS. 22:00 - 00 00 2.00 DRILL N DFAL 3,t70.00 INTI !WAIT ON ORDERS -NO CLEAN SURVEYS OBTAINED WHEN REACHING STOPPING POINT(3,175'MD)IN SURVEY PLAN. CANNOT DRILL AHEAD WITH CURRENT AC i SCAN AND SURVEY PLAN WITHOUT CLEAN 1SURVEYS. -CONSULT WITH TOWN ON PLAN FORWARD. -RECIPROCATE STRING IN 45'STROKES. 1-CIRCULATE PUMPS AT 450 GPM,940 PSI. HOLE MOTOR ORIENTATION AT 30 DEGREES LEFT OF HIGH SIDE. 5/6/2015 00 00 - 01:30 1.50 DRILL N DFAL 3,170.00 INTI WAIT ON ORDERS -NO CLEAN SURVEYS OBTAINED WHEN REACHING STOPPING POINT IN SURVEY PLAN. CANNOT DRILLAHEAD WITH CURRENT AC SCAN AND SURVEY PLAN WITHOUT CLEAN SURVEYS. -CONSULT WITH BP ODE AND ETL,SLB DIRECTIONAL PLANNER AND D&M MANAGER ON PLAN FORWARD. -RECIPROCATE STRING IN 45'STROKES. -CIRCULATE PUMPS AT 450 GPM,940 PSI. -HOLE MOTOR ORIENTATION AT 30 DEGREES LEFT OF HIGH SIDE. Printed 7/6/2015 11 00 17AM • North America-ALASKA-BP • Page 30 of 71 Operation Summary Report Common Well Name.07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date 4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release.6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT ' NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 04:30 I 3.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 3,170'MD TO 3,270'MD(3,237'TVD) 1 OBTAIN NEW AC SCAN FROM SLB TO ALLOW DRILLING ONE MORE STAND -450 GPM,1,060 PSI ON,990 PSI OFF. I -10K WOB,40 RPM,2K TORQUE ON,2K 1 TORQUE OFF. P/U 132K,S/O 126K,ROT 125K. -ECD:ACTUAL= 9.82 PPG,CALC=9.4 PPG. -SURVEY EVERY-30 FT. -ACTUAL ROTATE TIME=1.55 HRS -ACTUAL SLIDE TIME=2.42 HRS { 1-JARS TIME=3.87 HRS MUD WEIGHT:9.0 PPG IN,9.0 PPG OUT _ '-OBTAIN SLOW PUMP RATES AT 3,270'MD 04:30 - 05:00 I 0.50 , DRILL ! N 1 DFAL 3,268.00 INTI CIRCULATE TWO BOTTOMS UP -450 GPM,950 PSI I -RECIPROCATING 50' I -ECD:CALL,9.5 PPG,ACTUAL 9.65 PPG MONITOR WELL FOR 10 MINUTES:STATIC -MUD WEIGHT:9.0 PPG IN,9.0 PPG OUT_ 05:00 - 06:00 1.00 DRILL N DFAL 3,268.00. INTI PULL 8-1/2"INTERMEDIATE BHA INTO 1WINDOW FROM 3,268'MD TO 2,742'MD PJSM PRIOR TO POOH , POOH WATCHING FOR DOWN HOLE SWABBING-NONE OBSERVED 06:00 - 06:30 0.50 DRILL N DFAL 3,268.00 INTI CIRCULATE BOTTOMS UP AT THE WINDOW 1-450 GPM,940 PSI I-ECD:CALC 9.5 PPG,ACTUAL 9.65 PPG BLOW DOWN TOP DRIVE -LINE UP ON TRIP TANK 06:30 - 09:30 3.00 DRILL + N I DFAL 3,268.00 INTI WAIT FOR GYRO DATA AND HALLIBURTON I E-LINE 1 ! -NO ROTATION -NO CIRCULATION ' -CIRCULATE OVER TOP OF HOLE WITH TRIP 1 TANK TO MONITOR WELL ' SIMOPS INSTALLING VIDEO CAMERA IN THE DERRICK -WORKING ON HYDRAULIC LINES ON RIG FLOOR 09 30 - 10:00 0.50 DRILL N DFAL 3,268.00 INTI 1RIG UP HALLIBURTON E-LINE I-PJSM TO IDENTIFY LIFTING OPERATION HAZARDS.DISCUSS EXCLUSION ZONE I IMPLEMENTATION,LIFTING TOOL INSPECTION CERTIFICATION,AND THIRD PARTY RIG UP. SPOT E-LINE UNIT AND RU 10 00 - 12:00 2.00 DRILL N DFAL 3,268.00 INTI I WAIT FOR GYRO DATA -NO ROTATION -NO CIRCULATION 1 1 1 CIRCULATE OVER TOP OF HOLE WITH TRIP TANK TO MONITOR WELL RIG UP GYRO DATA I BRING TOOLS TO RIG FLOOR -h- _ _, PREP FOR RUNNING IN HOLE 12:00 - 12:30 0.50 DRILL N I DFAL 3,268.00 INTI RIG SERVICE -SERVICE TOP DRIVE -SERVICE DRAW WORKS 1 -GREASE CROWN Printed 7/6/2015 11:00:17AM North America-ALASKA-BP Page 31 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual l60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 13:00 0.50 DRILL N DFAL 3,268.00 INTI RIH ON ELEVATORS FROM 2,742'MD TO 3,248' IMD -MONITOR WELL ON TRIP TANK-STATIC 13:00 - 15:00 2.00 DRILL N DFAL 3,268.00 INTI RIH WITH GYRO DATA ON E-LINE AND SURVEY -PJSM WITH RIG CREW,GYRO DATA,AND HALLIBURTON 11-TAKE FIRST SURVEY AT 2,812'MD CONTINUE TO SURVEY AT 100'MD INTERVALS POOH WITH E-LINE AND GYRO DATA,LEAVE RIGGED UP ON RIG FLOOR 15:00 - 15:30 0.50 DRILL N DFAL 3,268.00 1' INTI WASH DOWN FROM 3,248'MD TO 3,270'MD STAGE PUMPS UP TO 450 GPM,1010 PSI -40 RPM,2K TORQUE -P/U 130K,S/O 125K,ROT 130K. -CIRCULATE BOTTOMS UP APPROVAL TO:PROCEED FROM ODE TO DRILL AHEAD WITH NEW SLB SURVEYS AND AC PLOT. 15:30 - 18:00 2.50 DRILL P INTI 1DRILL8-1/2"INTERMEDIATE HOLE FROM 13,270'MD TO 3,450'MD(3,385'TVD)550 GPM,1,450 PSI ON,1,400 PSI OFF. -10K WOB,40 RPM,3K TORQUE ON,2K TORQUE OFF. -P/U 135K,S/O 125K,ROT 126K. -ECD:ACTUAL= 9.9 PPG,CALC=9.6 PPG. SURVEY EVERY-30 FT. ACTUAL ROTATE TIME=1.56 HRS -ACTUAL SLIDE TIME=0.21 HRS JARS TIME=7.32 HRS ,-MUD WEIGHT:9.0 PPG IN,9.0 PPG OUT NO CLEAN SURVEYS,REACHED END OF AC PLOT WITH NO CLEAN SURVEYS -SLB AND ODE CALLED TD FOR BUILD BHA 18:00 - 18:30 0.50 DRILL N DFAL 3,450.00 INTI RIH WITH GYRO DATA ON E-LINE AND SURVEY I-SURVEY AT 100'MD INTERVALS AS NECESSARY -POOH WITH E-LINE AND GYRO DATA,LEAVE RIGGED UP ON RIG FLOOR 18:30 - 19:30 1.00 DRILL I P INTI CIRCULATE BOTTOMS UP WITH 30 BBL HIGH VIS SWEEP AROUND RECIPROCATING PIPE 45' -550 GPM,1,430 PSI -40 RPM,2K TORQUE MUD WEIGHT:9.0 PPG IN,9.0 PPG OUT -NO INCREASE IN CUTTINGS ON SWEEP'S !RETURN -OBTAIN SLOW PUMP RATES AT 3,450'MD Printed 7/6/2015 11:00:17AM 0 North America-ALASKA-BP S Page 32 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 I End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:OOAM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase j Description of Operations (hr) (usft) 19:30 - 22:00 2.50 DRILL P INTI MONITOR WELL FOR 10 MINUTES BEFORE PULLING OFF BOTTOM:STATIC POOH WITH 8-1/2"INTERMEDIATE BHA FROM 3,450'MD TO 950'MD h PJSM PRIOR TO POOH POOH WATCHING FOR DOWN HOLE SWABBING-NONE OBSERVED -11-MONITOR WELL ON TRIP TANK-HOLE 1 TAKING CORRECT HOLE FILL 1-MONITOR WELL FOR 10 MINUTES WHEN PULLING THROUGH WINDOW:STATIC -MONITOR WELL FOR 10 MINUTES BEFORE — LAYING DOWN BHA:STATIC -MUD WEIGHT:9.0 PPG IN,9.0 PPG OUT 22:00 - 00:00 2.00 DRILL P INTI LAY DOWN 8-1/2"INTERMEDIATE DRILLING I BHA. -LAY DOWN ENTIRE BHA AS DIRECTED BY 1 <SLB MVWD/DD. -MONITOR WELL ON TRIP TANK WHILE LAYING DOWN BHA 5/7/2015 00:00 - 01:00 1.00 DRILL P INTI I CLEAN AND CLEAR RIG FLOOR fCLEAR 2 NM STABILIZERS FROM RIG FLOOR DOWN BEAVER SLIDE CLEAR REMAINING BHA EQUIPMENT FROM FLOOR -PU 2 NEW NM STABILIZERS UP BEAVERS SLIDE 01:00 - 03:30 2.50 DRILL P INTI !MAKE UP 8-1/2"INTERMEDIATE RSS DRILLING BHA -PJSM DISCUSS WELL CONTROL DURING BHA M/U I-8.5"MDSI616 PDC,PD 675 X6 RSS,E-MAG RCVR,FLEX COLLAR,PERISCOPE 675 LWD, I TELESCOPE 675 MWD,8 3/8"NM STABILIZER, 9"RHINO REAMER,(3)NM FLEX COLLARS, I I 1 FLOAT SUB,(13 JTS)5"HWDP,HYDRAULIC I JARS,(7 JTS)5"HWDP, I-OAL OF BHA:882'MD --r 03:30 06:00 2.50 ii DRILL P INTI !RIH WITH 8-1/2"INTERMEDIATE RSS DRILLING BHA FROM 882'MD TO 2,780'MD RIH ON ELEVATORS WITH 4"DP FROM DERRICK. MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT. -SHALLOW HOLE TEST MWD:GOOD -550 GPM,W/1450 PSI 06:00 - 08:00 2.00 DRILL 1 P ', INT1 SLIP AND CUT DRILLING LINE 1 -PJSM FOR SLIP&CUT OPERATIONS- 1 REVIEW DDI PROCEDURE. -SLIP&CUT 60'OF DRILLING LINE. 11 INSPECT TOP DRIVE AND SAVER SUB-PER MANUFACTURER RECOMENDATIONS -CALIBRATE TOTCO BLOCK HIGHT AND MWD BLOCK HEIGHT Printed 7/6/2015 11 00 17AM 1110 North America-ALASKA-BP Page 33 of 71 r ; '/4- r Operation Summary Report Common Well Name 07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date 4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) j 08:00 - 10:00 It 2.00 DRILL P INTI 'RIH WITH DRILLING 8-1/2"INT 1 RSS BHA#2 -RIH ON ELEVATORS FROM 2,780'MD TO 3,445'MD(3389'TVD)(5')OFF BOTTOM. -OBTAIN 3 CHECK SHOTS FOR COMPARISON TO GYRO DATA -OBTAIN PARAMETERS AND TAKE SPR'S -PUW-140 K,SOW-137K -OBTAIN PRESSURE BENCHMARKS FOR REAMER ACTIVATION 125 GPM,230 PSI,45 RPM,2K TQ 550 GPM,1,720 PSI,45 RPM,2K TQ -DROP 1.25"OPENING BALL- ' MEASUREMENT VERIFIED BY WSL -PUMP DOWN AT 100 GPM W/200 PSI,WITH 45RPM,2K TQ -TOOK 277 STKS TO LAND BALL ON SEAT, i SHEAR REAMER WITH 1450 PSI STAGE PUMPS UP FROM 100 GPM TO 550 GPM,W/45 RPM&2.5 K TQ AND 1420 PSI -320 PSI PRESSURE DROP AT 550 GPM. INDICATION OF SUCCESSFUL REAMER OPENING } -REAM DOWN FROM 3,445'TO 3,450'MD TO CREATE LEDGE 550 GPM,1420 PSI,45K,2.5K TQ -SHUT DOWN ROTARY KEEP PUMP ON AND PULL UP.OBSERVE 5K OVERPULL WHEN 'PULLING UP TO 3,441 MD. I-SECOND POSITIVE INDICATION OF OPENING,VERIFY TURBIN RPM'S REDUCTION 10:00 00:00 14.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 3,450'MD TO 4,550'MD(4,32V TVD). i I 576 GPM, 2,050 PSI ON,2,100 PSI OFF. WOB 7K,120 RPM,5K TORQUE ON,4K !TORQUE OFF. -P/U 155K,S/O 136K,ROT 138K. -ECD:ACTUAL=10.93 PPG,CALC=10.5 PPG. -SURVEY EVERY-95 FT. -ACTUAL ROTATE TIME=9.35 HRS. -INCREASED MUD WEIGHT FROM 9.1 PPG TO 10.0 PPG FROM 3,791'MD TO 4,091'MD(-300' MD ABOVE SV1 PER THE DRILLING PROGRAM) -ESTABLISH SLOW PUMP RATES AT 3,450'MD AND AT 4,200'MD WITH NEW MW. -MUD WEIGHT:10.0 PPG IN,10.0 PPG OUT. -PUMP 30 BBLS HI-VIS SWEEP AT 3,815'MD, 10%INCREASE IN CUTTINGS IN RETURNS FROM SWEEP. -FLUID LOSS FOR THE DAY=0 BBLS Printed 7/6/2015 11 00 17AM 4111 • North America-ALASK,kA„-BP Page 34 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations -T—(hr) (usft) 5/8/2015 00:00 - 12:00 , 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 4,550'MD TO 5,410'MD(5,053'TVD) 585 GPM, 2,320 PSI ON,2,340 PSI OFF. -WOB 5K,140 RPM,5K TORQUE ON,4K TORQUE OFF. -P/U 163K,S/O 140K,ROT 148K. -ECD:ACTUAL=10.74 PPG,CALC=10.46 iPPG. -SURVEY EVERY-95 FT. ACTUAL ROTATE TIME=8.56 HRS. MUD WEIGHT:10.0 PPG IN,10.0 PPG OUT. -PUMP 30 BBLS HI-VIS SWEEP AT 4,768'MD, I 115%INCREASE IN CUTTINGS IN RETURNS FROM SWEEP. PUMP 30 BBLS HI-VIS SWEEP AT 5,117'MD, ,10%:INCREASE IN CUTTINGS IN RETURNS FROM SWEEP. i 1-ESTABLISH SLOW PUMP RATES AT 5,245' I MD. i -MUD WEIGHT:10.0 PPG IN,10.0 PPG OUT. '-INCREASED MUD LUBE CONCENTRATION I FROM 1.5%TO 2.5% '-CONDUCTED SPILL DRILL 12:00 - 00:00 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 5,410'MD TO 6104'MD(5,636'TVD) !-577 GPM, 2,540 PSI ON,2,520 PSI OFF. 1 WOB 5-10K,100 RPM,6-7K TORQUE ON, ! 5-6K TORQUE OFF. -P/U 179K,S/O 143K,ROT 156K. -ECD:ACTUAL=10.83 PPG,CALC=10.51 PPG. -SURVEY EVERY-95 FT. -ACTUAL ROTATE TIME=9.43 HRS. -MUD WEIGHT:10.1 PPG IN,10.1 PPG OUT. -PUMP 30 BBLS HI-VIS SWEEP AT 5,735'MD, 5%INCREASE IN CUTTINGS IN RETURNS I 1 ,FROM SWEEP. ESTABLISH SLOW PUMP RATES AT 5,719' MD. -FLUID LOSS FOR THE DAY=0 BBLS Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 35 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM i Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. I(JIM:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To ' Hrs Task Code NPT NPT Depth Phase ' Description of Operations (hr) (usft) 5/9/2015 00:00 - 12:00 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 6,104'MD TO 6,575'MD(6,032'TVD) -582 GPM, 2,660 PSI ON,2,620 PSI OFF. 1-WOB 5K,140 RPM,5-8K TORQUE ON,5-6K TORQUE OFF. I P/U 185K,S/0 146K,ROT 163K. ,-ECD:ACTUAL=10.90 PPG,CALC=10.55 'PPG. I I,SURVEY EVERY-93 FT. -ACTUAL ROTATE TIME=10.29 HRS. -TOTAL JAR TIME=45.03 1-TOTAL BIT TIME=37.63 1-MUD WEIGHT:10.1 PPG IN,10.1 PPG OUT. -PUMP 30 BBLS HI-VIS SWEEP AT 6,168'MD, 11 5%INCREASE IN CUTTINGS IN RETURNS FRAM SWEEP. PUMP 30 BBLS HI-VIS SWEEP AT 6,330'MD, 5%INCREASE IN CUTTINGS IN RETURNS FROM SWEEP. -INCREASED MUD LUBE CONCENTRATION FROM 2.5%TO 3% , ESTABLISH SLOW PUMP RATES -CONDUCTED FIRE DRILL,RESPONSE TIME ii_-1:15 ,12:00 - 00:00 12.00 DRILL P INTI 1DRILL 8-1/2"INTERMEDIATE HOLE FROM 6,575'MD TO 7,180'MD(6,541'TVD) -579 GPM, 2,840 PSI ON,2,830 PSI OFF. -WOB 7-10K,140 RPM,6-8K TORQUE ON, 16-7K TORQUE OFF. -P/U 195K,S/O 155K,ROT 170K. ECD:ACTUAL=10.82 PPG,CALC=10.56 PPG. 1-SURVEY EVERY-93 FT. -ACTUAL ROTATE TIME=9.77 HRS. I -TOTAL JAR TIME=54.80 -TOTAL BIT TIME=47.40 -MUD WEIGHT:10.1 PPG IN,10.1 PPG OUT. 1-PUMP 30 BBLS HI-VIS SWEEP AT 6,765'MD, 10%INCREASE IN CUTTINGS IN RETURNS FROM SWEEP. -PUMP 30 BBLS HI-VIS SWEEP AT 7,050'MD, 10%INCREASE IN CUTTINGS IN RETURNS FROM SWEEP. 1 -ESTABLISH SLOW PUMP RATES AT 6,673'MD CONDUCTED TABLE TOP KICK WHILE DRILLING DRILL WITH UNDER REAMER IN THE STRING _FLUID LOSS FOR THE DAY=0 BBLS t - 5/10/2015 00:00 - 02:00 I 2.00 I DRILL P INTI 1 DRILL 8-1/2"INTERMEDIATE HOLE FROM I 1 7,180'MD TO 7,318'MD 585 GPM, 3,050 PSI ON,3,090 PSI OFF. -WOB 9K,140 RPM,7-8K TORQUE ON.6K TORQUE OFF. -P/U 200K,S/O 156K,ROT 170K. I-ECD:ACTUAL=11.12 PPG,CALC=10.70 PPG. SURVEY EVERY-93 FT. -MUD WEIGHT:10.1 PPG IN,10.1 PPG OUT. -INCREASED MUD WEIGHT FROM 10.1 PPG TO 10.2 PPG FROM 7,200'MD TO 7,300'MD I I (-200'MD ABOVE CM2 PER THE DRILLING PROGRAM) Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP Page 36 of 71 ) `Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 1 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual(q160.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) (usft) 02:00 - 03:00 1.00 DRILL N RREP 7,300.00 INTI REPAIR MUD PUMP 1 LINER SEAL 1-STOP DRILLING AND ROTARY 1 I-CONTINUE TO CIRCULATE WITH MUD PUMP { I ' 12 !-410 GPM,1,700 PSI ,-RECIPROCATE PIPE IN 75'INTERVALS TO PREVENT BIT FROM COMING OUT OF PILOT HOLE. 03:00 - 12:00 9.00 DRILL 1 P ; INT1 DRILL 8-1/2"INTERMEDIATE HOLE FROM 7,318'MD TO 7,715'MD(6,988'MD) 1-585 GPM, 3,270 PSI ON,3,220 PSI OFF. -WOB 10K,140 RPM,8-9K TORQUE ON,7K TORQUE OFF. -P/U 205K,S/O 160K,ROT 174K. -ECD:ACTUAL=11.17 PPG,CALC=10.82 1 PPG. 1-SURVEY EVERY-93 FT j-ACTUAL ROTATING TIME=8.91 HRS. -TOTAL JAR TIME=63.71 -TOTAL BIT TIME=56.31 1-PUMP 30 BBLS HI-VIS SWEEP AT 7,428'MD, 5%INCREASE IN CUTTINGS IN RETURNS FROM SWEEP. INCREASED MUD WEIGHT FROM 10.2 PPG TO 10.4 PPG FROM 7,300'MD TO 7,320'MD i(ABOVE CM2 PER THE DRILLING PROGRAM) ESTABLISH SLOW PUMP RATES WITH NEW MW AT 7,335'MD. -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT. -CONDUCTED KICK WHILE DRILLING DRILL WITH UNDER REAMER IN THE STRING 12:00 - 00:00 12.00 DRILLINT1_ i P �DRILL 8-1/2°INTERMEDIATE HOLE FROM 7,715'MD TO 8,300'MD(7,480'MD) -579 GPM, 3,440 PSI ON,3,440 PSI OFF. -WOB 10-12K,140 RPM,8-9K TORQUE ON, 6-8K TORQUE OFF. P/U 219K,S/O 163K,ROT 180K. -ECD:ACTUAL=11.23 PPG,CALC=10.79 PPG. -SURVEY EVERY-93 FT -ACTUAL ROTATING TIME=10.61 HRS. -TOTAL JAR TIME=66.92 -TOTAL BIT TIME=74.32 -PUMP 30 BBLS HI-VIS SWEEP AT 7,928'MD, 15%INCREASE IN CUTTINGS IN RETURNS FROM SWEEP. -ESTABLISH SLOW PUMP RATES AT 7,810'MD AND 8,188'MD. MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT. -CONDUCTED SPILL DRILL -FLUID LOSS FOR THE DAY=0 BBLS Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 37 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12.00:OOAM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual g60.72usft(above Mean Sea Level) Date I From-To Hrs Task Code I NPT NPT Depth ! Phase Description of Operations (hr) ! (usft) 5/11/2015 100:00 - 12:00 12.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 8,300'MD TO 8,698'MD(7,480'MD) ! -550 GPM, 3,390 PSI ON,3,330 PSI OFF. I I-WOB 10K,120 RPM,7-10K TORQUE ON,6-8K I I TORQUE OFF. -P/U 220K,S/O 170K,ROT 187K. ECD:ACTUAL=11.01 PPG,CALC=10.79 PPG. -SURVEY EVERY-93 FT ACTUAL ROTATING TIME=10.38 HRS. -TOTAL JAR TIME=84.7 -TOTAL BIT TIME=77.3 -PUMP 30 BBLS HI-VIS SWEEP AT 8,475'MD, 15%INCREASE IN CUTTINGS IN RETURNS !FROM SWEEP. -ESTABLISH SLOW PUMP RATES AT 8,569' MD. MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT. -CONDUCTED TABLE TOP MAN DOWN DRILL 12:00 - 18:30 6.50 I DRILL P INTI I DRILL 8-1/2"INTERMEDIATE HOLE FROM 18,698'MD TO 9,046'MD(8,122'MD) I-550 GPM, 3,540 PSI ON,3,480 PSI OFF. WOB 9-11,140 RPM,8-9K TORQUE ON,7-8K [TORQUE OFF. 1-P/U 233K,S/O 170K,ROT 190K. -ECD:ACTUAL=11.49 PPG,CALC=10.9 PPG. I-SURVEY EVERY-93 FT 1-MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT. 18:30 - 19:00 0.50 DRILL P INTI !CONDUCT WEEKLY BOP FUNCTON TEST i PERFORM PJSM -FUNCTION BOTTOM(3-1/2"X 6"VBR)AND ' ANNULAR ON 4"PIPE II -FUNCTION HCR KILLAND HCR CHOKE ALL FUNCTION PROPERLY-WILL TEST 7" RAMS AND BLIND RAMS WHEN OUT OF HOLE -1-- 19.00 00:00 5.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 9,046'MD TO 9,236(8,286'MD) -550 GPM, 3,540 PSI ON,3,480 PSI OFF. I-WOB 9-10K,140 RPM,8-9K TORQUE ON, I 17-8K TORQUE OFF. P/U 233K,S/O 170K,ROT 190K. ' -ECD:ACTUAL=11.24 PPG,CALC=10.9 PPG. -SURVEY EVERY-93 FT -ACTUAL ROTATING TIME=10.24 HRS. -TOTAL JAR TIME=94.82 -TOTAL BIT TIME=87.42 -PUMP 30 BBLS HI-VIS SWEEP AT 8,949'MD, , 5%INCREASE IN CUTTINGS IN RETURNS 'FROM SWEEP. -PUMP 30 BBLS HI-VIS SWEEP AT 9,137'MD, 5%INCREASE IN CUTTINGS IN RETURNS FROM SWEEP. ESTABLISH SLOW PUMP RATES AT 8,949' MD. I -MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT. -CONDUCTED FIRE DRILL Printed 7/6/2015 11:00:17AM • North America-ALASKA BP age 38 of 71 Operation Summary Report Common Well Name 07-07A AFE No Event Type RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date.6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM I Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date j From-To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) _.. (usft) 5/12/2015 00:00 - 04:30 4.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 8,446'TO 9,236'MD(7,604'TVD) -550 GPM, 3,540 PSI ON,3,480 PSI OFF. 140 RPM,9K TQ ON,7-8K TQ OFF,8K WOB P/U 240K,S/O 175K,ROT 195K. ECD:ACTUAL=11.29 PPG,CALC=10.88 PPG. SURVEY EVERY-93 FT -ART=4.36 HRS MW=10.5+PPG IN/10.6 PPG OUT LOSSES OBSERVED AT-9,330'MD(35 BPH j LOSS RATE)-DISCUSSED WITH ODE AND BEGAN MIXING DRILLAHEAD PILL 04 30 - 06 30 2.00 DRILL P INTI CONTROL DRILL FOR SAG CASING PICK -P/U 4"DP SINGLE AND CONTROL DRILL W/ CONSTANT PARAMETERS 8K WOB -BEGIN CONTROL DRILLING WITH CONSTANT PARAMETERS AT 9,175'MD I OBSERVED REVERSE DRILLING BREAK AT 9,445'MD AND DRILLING BREAK TO 9,450'MD (8,466'TVD) -ROTATE AT 45 RPM W/7K TQ AND RECIPROCATE 75'WHILE CIRCULATING BU jFOR SAMPLE-SAMPLES CONFIRM IN THE SAG FLUID LOSSES-25 BPH I 06:30 - 07:00 0.50 DRILL P * INTI CLOSE RHINO REAMER -OBTAIN PARAMETERS PRIOR TO DROPPING RHINO REAMER DEACTIVATION BALL -550 GPM,3,300 PSI,7K TQ,2,656 X6 TURBINE RPM -DROP 1.625"DEACTIVATION BALL AND PUMP DOWN AT 225 GPM FOR 10 MIN (-5,100').SLOW TO 125 GPM UNTIL BALL ON SEAT.PRESSURE UP TO 1,910 PSI AND OBSERVED REAMER CLOSE. OBTAIN PARAMETERS TO COMPARE WITH REAMER OPEN -550 GPM,3,430 PSI,7K TQ,2,890 X6 TURBINE RPM -130 PSI INCREASE AND 234 X6 TURBINE RPM INCREASE CONFIRM RHINO REAMER CLOSED 07:00 - 09:00 2.00 DRILL P INTI PUMP HI-VIS SWEEP&CBU PRIOR TO SHORT TRIP -550 GPM,3,475 PSI -120 RPM,BK TQ -ROTATE AND RECIPROCATE PIPE 75'WHILE CBU 3X -FLUID LOSSES 0 BPH 'DISCOVERED WELLBORE HAD NOT BEEN TAKING FLUID.FLUIDS FROM PITS WERE BEING REDIRECTED TO THE ROCKWASHER DUE TO IMPROPER LINEUP OF CENTRIFUGE. SEE TRACTION REPORT#2015-IR-4997932 Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 39 of 71 Operation Summary Report Common Well Name.07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. I UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) ! (usft) ' I 09:00 - 11:00 2.00 DRILL I P ' INTI PUMP OUT OF HOLE TO TOP OF HRZ(8,663' MD)FOR SHORT TRIP TO WINDOW -PJSM FOR PUMPING OUT OF HOLE.REVIEW DDI SOP AND DISCUSS FLUID MONITORING, 1 !TRIP SHEETS,AND OPERATION OF MUD BUCKET WHILE BREAKING OUT OF TOP i DRIVE FLOW CHECK WELLBORE FOR 10 MINS I PRIOR TO PULLING OFF BOTTOM-STATIC I-LAY DOWN 4"DP SINGLE I-PUMP OUT OF HOLE FROM 9,427'TO 8,571' MD AT 50 FPM,2 BPM,200 PSI '-NO OVERPULLS OBSERVED 11.00 - 16:30 5.50 DRILL P I INTI POOH ON ELEVATORS FROM 8,571'TO 2,768' MD FOR SHORT TRIP TO WINDOW I -FLOW CHECK WELLBORE FOR 10 MINS 'PRIOR TO BLOWING DOWN TOP DRIVE- STATIC I-BLOW DOWN TOP DRIVE I-P/U 205K,S/0 150K AT 7,527'MD -MONITOR TRIP ON TRIP TANK I-MW=10.5 PPG IN/OUT NO OVERPULL OBSERVED WHEN PULLING -RHINO REAMER AND BHA THROUGH ;WINDOW I 1-FLOW CHECK WELLBORE FOR 10 MINS AFTER PULLING THROUGH WINDOW-ON MINIMAL STATIC LOSSES 16:30 - 18:00 1.50 DRILL P INTI I CIRCULATE PRIOR TO MAKING WIPER TRIP TO TD CBU 2X AND CONDITION MUD SYSTEM RECIPROCATE PIPE 95'WHILE CIRCULATING -500 GPM,1,660 PSI ON THE UP STROKE -400 GPM,1,080 PSI ON THE DOWN STROKE -BLOW DOWN TOP DRIVE -MW=10.5 PPG IN/OUT 18:00 - 18:30 0.50 j DRILL P INTI I RIG SERVICE -LUBRICATE TOP DRIVE AND BLOCKS 18:30 - 00:00 5.50 DRILL P INTI I MAKE WIPER TRIP WITH DRILLING BHA FROM 2,768'TO 8,951'MD I -RIH ON ELEVATORS BREAK CIRCULATION EVERY 1,900'MD.350 GPM,1,370 PSI I I -MONITOR TRIP ON TRIP TANK -MW=10.5 PPG IN/OUT , I I-ENCOUNTER TIGHT SPOT AT 7,843'MD WITH 115K DOWN.PU AND SET 15K DOWN SECOND TIME. KELLY UP AND ESTABLISH PARAMETERS P/U=210K,S/O=158K,ROT=175K I -132 GPM,740 PSI,25 RPM,5K TQ -REAM DOWN FROM 7,805'TO 7,907'MD. -TURN OFF ROTARY AND PUMPS.WORK I i THROUGH WITH NO ADDITIONAL WEIGHT Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 40 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 1Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) l (usft) 5/13/2015 00:00 - 02:30 2.50 DRILL P INTI MAKE WIPER TRIP WITH DRILLING BHA FROM 8,951'TO 9,450'MD RIH ON ELEVATORS. I I-ENCOUNTER TIGHT SPOTS AT 9,094',9,100'. I 19,182',9,350'MD WITH 15K DOWN.P/U AND I SET 15K DOWN SECOND TIME. -KELLY UP AND REAM THROUGH TIGHT ;SPOTS. I-P/U=205K,S/O=165K,ROT=180K. [ -168 GPM,740 PSI,50 RPM,7-8K TQ. '-TURN OFF ROTARY AND PUMPS.WORK THROUGH WITH NO ADDITIONAL WEIGHT. -P/U 4"DP SINGLE. -TAG UP ON PILOT HOLE AT 9,362'MD WITH ' 15K DOWN. 1-MAKE SECOND ATTEMPT AND SET 15K DOWN. REAM FROM 9362'TO 9,450'MD. -NO FILL ON BOTTOM. 02:30 - 05.30 3.00 DRILL P 1 INTI CONDITION HOLE PRIOR TO POOH 1 -550GPM,3,618 PSI,100 RPM,8-9K TORQUE. I I-RECIPROCATE PIPE 75'WHILE CIRCULATING. I PUMP 30 BBL HI VIS SWEEP. -CBU 3X. P/U 245K,S/O 175K,ROT 190K. -OBSERVE 10%INCREASE IN CUTTINGS AT i 'SURFACE FROM SWEEP. 05:30 - 07.00 1.50 DRILL P INTI 'PUMPING OUT OF HOLE -PJSM ON PUMPING OUT OF HOLE. FLOW CHECK FOR 10 MIN. WELL STATIC. !-PUMP OUT OF HOLE AT 2 BPM 320 PSI WHILE PULLING 50 FPM F/9450'T/8571'TO ABOVE TOP OF HRZ. 1 !-NO OVERPULL OBSERVED. _ !*1 BPH STATIC LOSS RATE. 07:00 - 07:30 0.50 DRILL P ' INT1 PREPARE TO POOH ON ELEVATORS I -BLOW DOWN TOP DRIVE. -LINE UP ON TRIP TANK TO POOH ON ELEVATORS. I RACK BACK ONE STAND. 07:30 - 08:30 1.00 DRILL C INTI RIH ON ELEVATORS F/8476'TO T/9445' -RECEIVE ORDERS FROM ODE AND I ANCHORAGE OFFICE TO RIH TO TD AND CBU FOR SAMPLES I I -TAG 5'OF FILL ON BOTTOM. POOH 50'AND STAGE THE PUMP RATE TO 550 GPM AT 3690 PSI. ' 1_ I -WASH DOWN F/9445'T/9450'TD. Printed 7/6/2015 11:00:17AM ill/ • North America-ALASKA-BP Page 41 of 71 Operation Summary Report Common Well Name:07-07A v AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. I UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs I Task I Code NPT NPT Depth I Phase 1 Description of Operations (hr) I (usft) 08:30 - 17:00 8.50 DRILL C INTI CBU FOR SAMPLES AND WEIGHT UP MUD SYSTEM TO 10.8 PPG PER OPERATIONS !CHANGE NOTICE#3 I -PUMP 30 BBLS HI VIS SWEEP. -CONTINUE CIRCULATING AT 500 GPM,2900 PSI,RECIPROCATE 75',AND ROTATE DRILL 1 STRING AT 100 RPM WHILE WEIGHTING UP I THE MUD SYSTEM FROM 10.5 PPG TO 10.8 PPG. 1 REDUCE THE PUMP RATE FROM 500 GPM TO 410 GPM AT 2140 PSI WHEN SLACKING I I OFF DRILL STRING. I-OBSERVE 5%INCREASE IN CUTTINGS AT I 1SURFACE FROM SWEEP. I-TAKE SPRs WITH NEW MUD WEIGHT. 17:00 18:00 1.00 DRILL 1 C INTI 1CBU FOR SAMPLES AFTER WEIGHT UP MUD SYSTEM TO 10.8 PPG PUMP 30 BBLS HI VIS SWEEP. 1 -CONTINUE CIRCULATING AT 500 GPM,2900 PSI,RECIPROCATE 75',AND ROTATE DRILL STRING AT 100 RPM WHILE. I-REDUCE THE PUMP RATE FROM 500 GPM , TO 410 GPM AT 2140 PSI WHEN SLACKING OFF DRILL STRING. '-OBSERVE 5%INCREASE CUTTINGS AT SURFACE FROM THE SWEEP STILL CONTAINED MINIMAL SHALE SAMPLES. 18:00 - 20.30 2.50 DRILL C INTI I PUMPING OUT OF HOLE FOR WIPER TRIP TO IABOVE HRZ I-PJSM ON PUMPING OUT OF HOLE. I FLOW CHECK FOR 10 MIN. WELL STATIC. -ESTABLISH PARAMETERS,P/U 243K,S/O 166K,ROT 195K. -PUMP OUT OF HOLE AT 2 BPM 310 PSI I WHILE PULLING 50 FPM F/9450'T/8666'TO ABOVE TOP OF HRZ. TIGHT SPOT AT 9305'WITH 15K OVERPULL. UNABLE TO WORK THROUGH. -BACKREAM THROUGH AT 25 RPM. -STOP ROTATING/PUMPING AND WORK THROUGH SPOT SLICK. TIGHT SPOT AT 9005'WITH 15K OVERPULL. S/O AND WORK THROUGH SLICK WITHOUT BACKREAMING. I 1 BPH STATIC LOSS RATE. 20:30 - 21:00 0.50 DRILL C INTI POOH ON ELEVATORS TO 8476' -MONITOR WELL 10 MIN. WELL STATIC. MUD WEIGHT 10.8 IN/OUT. 1-CONTINUE POOH ON ELEVATORS F/8666' T/8476'. I HOLE SLICK,NO TIGHT SPOTS. -P/U 25K,S/O 160K,AT 8666'. 21 00 - 21:30 0.50 DRILL C INTI RIH ON ELEVATORS TO 9331' -RIH ON ELEVATORS F/8666'T/9331'. -HOLE SLICK. NO TIGHT SPOTS. Printed 7/6/2015 11.00:17AM 0 North America-ALASKA-BP a Page 42 of 71 Operation Summary Report ; ti, Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM i Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To � Hrs I Task Code NPT ', NPT Depth II Phase Description of Operations (hr) _ I (usft) 1-21:30 - 22:00 0.50 DRILL C INTI P/U ONE JOINT OF 4"DRILL PIPE AND RIH TO j 9450'TD I -P/U ONE JOINT OF 4"DRILL PIPE AND RIH F/9331'T/9363'. 1 -M/U TOP DRIVE AND CONTINUE RIH TO TD. 1-TAG ONE FOOT HIGH AT 9449'WITH 15K 1 WOB. 1 BREAK CIRCULATION AND STAGE PUMP RATE UP TO 500 GPM,3040 PSI. WASH DOWN ONE FOOT TO 9450'TD WITH 15K WOB. -MAINTAIN FULL RETURNS. MAX ECD= 11.28. 22:00 - 23:00 1.00 I DRILL C INTI PUMP SWEEP AND OBSERVE BU SAMPLES PUMP 30 HI VIS SWEEPAT 3 BPM,370 PSI. —STAGE PUMP RATE TO 500 GPM,3040 PSI AND CIRCULATE OUT SWEEP. 1 i 1-CATCH BU SAMPLE AND SAMPLE FROM I SWEEP AT SURFACE. 1 -OBSERVE 0%INCREASE IN CUTTINGS WITH 'SWEEP AT SURFACE. -SAMPLES CONTAINED SAG RIVER SAND ' WITH NO EVIDENCE OF UP HOLE SHALES. :-DISCUSSED SAMPLES WITH ODE. "-RECEIVE APPROVAL FROM ODE TO iPROCEED WITH POOH TO RUN 7"LINER. 23:00 - 00:00 1.00 DRILL 1 P INTI PUMP OUT OF HOLE TO ABOVE HRZ -PJSM FOR PUMPING OUT OF HOLE. TAKE SPR's. -10 MIN FLOW CHECK. WELL STATIC. -PUMP OUT OF HOLE F/9450'T/9141'AT 2 BPM,310 PSI,40-50 FPM. j HOLE SLICK. NO TIGHT SPOTS. _ P/U 240K,S/O 165K. 5/14/2015 00:00 - 01:00 1.00 DRILL P INTI 1 PUMP OUT OF HOLE TO ABOVE HRZ 1-PJSM FOR PUMPING OUT OF HOLE. -PUMP OUT OF HOLE ABOVE THE HRZ FROM 9141'TO 8571'AT 2 BPM,320 PSI,40-52 FPM. HOLE SLICK. NO TIGHT SPOTS. 101:00 - 07:30 6.50 DRILL 1 P INTI POOH ON ELEVATORS FROM 8571'TO 913' -BLOW DOWN TOP DRIVE. -LINE UP ON TRIP TANK. -CONTINUE POOH ON ELEVATORS FROM 8571'TO 913'. HOLE SLICK. NO TIGHT SPOTS. I I -CONDUCT 10 MIN FLOW CHECK AFTER POOH INSIDE 9 5/8"WINDOW. WELL STATIC. I -DROP 2"DRIFT WITH 100'WIRE AT STD#21. I -RECOVER THE 2"DRIFT ON TOP OF THE UNDER REAMER. CONDUCT UN-ANNOUNCED D-1 TRIP DRILL I I 1WITH RIG CREWAND BP WSL. THE DRILL ,WAS WITNESSED AND ASSESSED BY A BP WELL CONTROL AUDITOR FROM HOUSTON. Printed 7/6/2015 11:00:17AM 0 North America-ALASKA-BP 0 Page 43 of 71 Operation Summary Report , Common Well Name 07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay , Site:PB DS 07 Rig Name/No.:DOYON 14 1 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UW:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT 1 NPT Depth Phase Description of Operations (hr) , (usft) -i 07:30 - 08:00 0.50 DRILL P INTI FLOW CHECK WELL BEFORE PULLING BHA !THROUGH BOPE CONDUCT 10 MIN FLOW CHECK BEFORE PULLING BHA NON-SHEARABLE TOOLS I THROUGH THE BOPE. WELL STATIC, SIMOPS -HOLD PJSM ON RACKING BACK 5"HWDP IN DERRICK. 1 08:00 09:00 1.00 DRILL 1 P INTI HANDLE BHA 1 -CHANGE OUT ELEVATORS FROM 4"TO 5" j !FOR HANDLING 5"HWDP. 1-RACK BACK 2 STDS 5"HWDP IN DERRICK. -L/D 2 JTS 5"HWDP AND HYDRAULIC JARS IN PIPE SHED. RACK BACK REMAINING 4 STDS 5"HWDP. 09:00 - 12:00 I 3.00 ! DRILL P INTI ,UD 8 1/2"X 9"BHA I-PJSM ON UD BHA. I-L/D 3 NM FLEX COLLARS,2 STABILIZERS, UNDER REAMER,MWD,POWER DRIVE RSS, I AND BIT. BIT GRADE 3-3-I. I I I � LOSSES FOR TOUR=8 BBLS. 12:00 - 14:30 2.50 DRILL P INTI !CLEAN RIG FLOOR AREA AND MOBILIZE 7" HANDLING EQUIPMENT TO RIG FLOOR I-PJSM ON UD BHA TOOLS DOWN BEAVER l SLIDE. -MOBILIZE 7"LINER HANDLING EQUIPMENT I TO RIG FLOOR. 14:30 - 17:00 2.50 CASING P INTI I RACK BACK 7"LINER HANGER ASSEMBLY IN DERRICK PJSM ON M/U 7"LINER HANGER ASSEMBLY AND RACK BACK IN THE DERRICK 1-M/U 7"LINER HANGER ASSEMBLY ONTO 7" 'JOINT OF CASING AND RACK BACK !ASSEMBLY IN THE OFF-DRILLER SIDE OF THE DERRICK. 17:00 - 19:00 2.00 CASING P INTI 1PREPARE SAFETY JOINT,7"CASING X-O TO FOSV,AND MOBILIZE VOLANT TOOL TO RIG FLOOR -PJSM ON PREPARING TOOLS AND MOBILIZING VOLANT TOOL TO RIG FLOOR. ,-M/U 7"LIFTER TO THE SAFETY JOINT. M/U 7"CASING X-O TO FOSV. -MOBILIZE THE VOLANT TOOL TO THE RIG FLOOR AND R/U ON TOP DRIVE. Printed 7/6/2015 11.00.17AM • North America-ALASKA-BP Page 44 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date 4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) -- (usft) — 19:00 00:00 5.00 CASING P INTI RUN 7"26#L-80 VT HC INTERMEDIATE LINER -PJSM ON RUNNING 7"LINER. -RUN 7"26#L-80 VT HC LINER TO 959'MD. -CHECK FLOATS. OK. -USE JET LUBE PIPE DOPE. I-TORQUE CONNECTIONS TO 11950 FT-LBS. -RUN 1 STRAIGHT BLADE CENTRALIZER LOCKED DOWN 5'FROM SHOE ON SHOE JOINT -RUN 1 STRAIGHT BLADE CENTRALIZER MID JOINT ON FLOAT COLLAR JOINT. -RUN 1 FLOATING HYDROFORM CENTRALIZER ON LANDING COLLAR JOINT. CONTINUE RUNNING 1 FLOATING HYDROFORM CENTRALIZER ON SLICK JOINTS 1-20. FILL CASING EVERY 10 JOINTS. -P/U 75K,S/O 75K AT 959'. -RIH AT 20-25 FPM FROM SURFACE TO 959' TO MINIMIZE LOSSES. *PERFORM PRACTICE RUN TO P/U AND STAB FOSVASSEMBLY ONTO LINER STRING TO [IDENTIFY OPERATIONS ISSUES AND 'RESOLVE SAME. 5/15/2015 00:00 - 05:00 5.00 CASING P INTIRUN 7"26#L-80 VT HC INTERMEDIATE LINER -CONTINUE RUNNING 7"26#L-80 VT HC I LINER TO 2735'MD. USE JET LUBE PIPE DOPE. TORQUE CONNECTIONS TO 11950 FT-LBS. CONTINUE RUNNING 1 FLOATING ,HYDROFORM CENTRALIZER ON SLICK JOINTS 21-35. -RIH AT 20-30 FPM FROM SURFACE TO 2735' !MD TO MINIMIZE LOSSES. -FILL CASING EVERY 10 JOINTS. I-OBTAIN PU/SO WEIGHTS EVERY-420'. -P/U 114K,S/O 114K AT 2735'. MUD WEIGHT 10.8 PPG IN/OUT. 05:00 - 06.30 1.50 CASING ! P INTI CIRCULATE 1.5 X BOTTOMS UP AT 9 5/8" WINDOW -CIRCULATE 1.5 X BOTTOMS UP AT 9 5/8" I WINDOW. STAGE PUMP RATE UP TO 3 BPM,230 PSI IN 0.5 INCREMENTS. Printed 7/6/2015 11 00 17AM III f� , North America ALASKA-BP Pa9s45 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site.PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12.00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI.500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft)06:30 - 12:00 5.50 CASING P INTI RUN 7"26#L-80 VT HC INTERMEDIATE LINER -CONTINUE RUNNING 7"26#L-80 VT HC LINER TO 4382'MD. CHECK FLOATS. OK. -USE JET LUBE PIPE DOPE. -TORQUE CONNECTIONS TO 11950 FT-LBS. -RIH AT 30 FPM FROM 2735'TO 4382'MD TO MINIMIZE LOSSES. -FILL CASING EVERY 1 JOINT. 1-BREAK CIRCULATION EVERY-410'AT 3 BPM FOR 5 MINUTES. OBTAIN PU/SO WEIGHTS EVERY-420'. -P/U 142K,S/O 128K AT 4382'. -MUD WEIGHT 10.8 PPG IN/OUT. *LOSSES WHILE RIH=23 BBLS. *TOTAL LOSSES FOR TOUR=28 BBLS. *HOLD KICK WHILE RUNNING 7"CASING DRILL. 12:00 - 20:30 8.50 CASING P INTI RUN 7"26#L-80 VT HC INTERMEDIATE LINER -CONTINUE RUNNING 7"26#L-80 VT HC LINER TO 6362'MD. -USE JET LUBE PIPE DOPE. -TORQUE CONNECTIONS TO 11950 FT-LBS. RIH AT 30-40 FPM FROM 4382'TO 6362'MD TO MINIMIZE LOSSES. -FILL CASING EVERY 1 JOINT. -BREAK CIRCULATION EVERY-410'AT 3 BPM FOR 5 MINUTES. -OBTAIN PU/SO WEIGHTS EVERY-410'. I-P/U 210K,S/O 165K AT 6362'. -MUD WEIGHT 10.8 PPG IN/OUT. -CIRCULATE CASING DOWN FROM 6392'TO 6775'MDAT 128 GPM,530 PSI. *COMPLETE RUNNING 7"LINER=3 JT SHOE TRACK+161 SLICK JTS. + *LOSSES WHILE RIH=39 BBLS. 20:30 - 21:00 0.50 CASING P INTI R/D VOLANT TOOL AND CHANGE OUT ELEVATORS -R/D VOLANT TOOL. -CHANGE OUT CASING ELEVATORS TO DRILL PIPE ELEVATORS. -L/D 4'TOP DRIVE BAILS EXTENSIONS. -M/U 7"VAM TOP X 4"XT-39 X-O BETWEEN 7" LINER AND STAND OF DRILL PIPE. Printed 7/6/2015 11 00 17A • North America-ALASKA-BP • Page 46 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12.00.00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 21:00 HMAN 00:00 3.00 CASING N 6,700.00 r INTI STAGE PUMP RATE UP AND CIRCULATE WHILE DISCUSSING FORWARD PLAN WITH ANCHORAGE OFFICE -STAGE PUMP RATE UP TO 3 BPM,410 PSI AND CIRCULATE WHILE DISCUSSING THE FORWARD PLAN WITH ANCHORAGE OFFICE. DECISION MADE TO POOH AND UD 7"LINER 'DUE TO BAKER LINER HANGER ASSEMBLY HAVING THE WRONG X-O INSTALLED BETWEEN THE HRD-E ZXPN LINER TOP PACKER AND THE FLEX-LOCK LINER HANGER. -MAINTAIN FULL RETURNS. *AOGCC 24 HR BOP TEST NOTIFICATION MADE ON 15 MAY 2015 AT 2210 HRS. *AOGCC BOP TEST WITNESS WAIVED BY JOHNNY HILL VIA E-MAIL ON 15 MAY 2015 AT 2218 HRS. 5/16/2015 00:00 01:00 1.00 CASING N HMAN INTI CIRCULATE AND CONDUCT PJSM -CONDUCT PJSM FOR L/D 7"LINER WHILE FINISH CBU FROM 7"LINER SHOE AT 6775'. 01:00 - 01:30 0.50 CASING N HMAN INTI PREPARE 7"HANDLING EQUIPMENT TO LID 7" LINER -PJSM. RACK BACK ONE STD OF 4"DRILL PIPE. I I I-BREAK DOWN X-Os. M/U X-O TO THE FOSV. -BLOW DOWN TOP DRIVE. -CHANGE FROM 4"DRILL PIPE ELEVATORS TO 7"LINER ELEVATORS. *TAKE SLOW PUMP RATES. 01:30 - 12:00 10.50 CASING N HMAN INTI POOH AND L/D 7"LINER L/D 7"26#L-80 VT LINER FROM 6775'TO SURFACE. r I LOSSES WHILE POOH=0 BBLS. 12:00 - 14:00 2.00 CASING N HMAN 6,700.00 INTI BREAK DOWN AND LAY OUT THE 7"LINER HANGER ASSEMBLY IN THE PIPE SHED -PJSM. 1 JOINT 7"LINER MADE UP UNDER LINER HANGER. -LINER TOP PACKER WITH PLUG ASSEMBLY. -X-Os. -1-4"P/J. 14:00 - 15.30 1.50 CASING N HMAN 6,700.00 INTI R/D 7"CASING TOOLS AND ASSOCIATED EQUIPMENT -PJSM. -R/D 7"CASING TOOLS AND ASSOCIATED I EQUIPMENT AND REMOVE FROM RIG FLOOR. 15 30 - 16:00 0.50 BOPSUR P INTI I PULL WEAR BUSHING PJSM. PULL WEAR BUSHING AND REMOVE FROM RIG FLOOR. 16:00 - 16.30 1 0.50 BOPSUR ', P INT1 I WASH OUT BOPS -PJSM. I-WASH OUT BOPS WITH WASH TOOL AT 391 GPM,60 PSI,100 RPM. BLOW DOWN TOP DRIVE. Printed 7/6/2015 11 00.17AM 4110 North America-ALASKA-BP • Page 47 of 71 Operation Summary Report s` Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00.00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth 1 Phase Description of Operations (hr) (usft) 16:30 - 18:30 1 2.00 BOPSUR P INTI R/U TO PRESSURE/FUNCTION TEST BOPE 1 1 -M/U 2-FOSV AND DART VALVES FOR TESTING. 1 -R/U BOP TEST EQUIPMENT. -DRAIN DRILLING FLUID OUT OF BOP STACK. 1 -R/U FILL-UP LINE ON INNER ANNULUS. 18:30 - 00:00 5.50 BOPSUR P , INT1 TEST BOPE TO 250 PSI LOW,3500 PSI HIGH 1 FOR 5 MINUTES EACH -TEST ON 4",4 1/2",AND 7"TEST JOINTS. -4"TEST JT-ANNULAR,LOWER PIPE RAMS 1 -7"TEST JT -UPPER PIPE RAMS,CHOKE MANIFOLD,FOSV AND DART VALVES I -4 1/2"TEST JT -LOWER PIPE RAMS -PERFORM D-1 TRIP DRILL. WELL SECURED 2:37 MIN. i-PERFORM ACCUMULATOR DRAW DOWN TEST. -TEST WITNESS WAIVED BYAOGCC REP JOHNNY HILL 15 MAY 2015,2218 HRS. .� 1LOSSES FOR TOUR=8 BBLS. 5/17/2015 00:00 - 05:00 5.00 BOPSUR P r INTI CONTINUE TESTING BOPE TO 250 PSI LOW, ,'3500 PSI HIGH FOR 5 MINUTES EACH r-TEST ON 4",4 1/2",AND 7"TEST JOINTS. 1 >4"TEST JT-ANNULAR,LOWER PIPE RAMS >7"TEST JT-UPPER PIPE RAMS,CHOKE MANIFOLD,FOSV/DART VALVES,TOP DRIVE (VALVES >4 1/2"TEST JT-LOWER PIPE RAMS - ALL TESTS CHARTED. -TEST WITNESS WAIVED BYAOGCC REP JOHNNY HILL 15 MAY 2015,2218 HRS. NOTE: TOP DRIVE UPPER HYDRAULIC IBOP I FAILED PRESSURE TEST. 05:00 - 06:30 1.50 BOPSUR P i INTI R/D BOPE TEST EQUIPMENT 1-R/D TEST EQUIPMENT AND FLOOR VALVES. DRAIN BOPS. -BLOW DOWN CHOKE/KILL LINES,CHOKE MANIFOLD,AND TOP DRIVE. ' I -PULL TEST PLUG. t 06:30 10:30 4.00 BOPSUR N I RREP INTI CHANGE OUT TOP DRIVE UPPER HYDRAULIC IBOP -PJSM. -LINE UP AND MONITOR WELL ON TRIP TANK. -CHANGE OUT TOP DRIVE UPPER HYDRAULIC IBOP. -R/U AND TEST TOP DRIVE IBOP TO 250 PSI I LOW,3500 PSI HIGH FOR 5 MINUTES EACH TEST. GOOD TEST. 10:30 11:00 0.50 BOPSUR N RREP 1 INTI R/D BOPE TEST EQUIPMENT -R/D BOPE TEST EQUIPMENT. jL/D 1 JOINT OF 4"DRILL PIPE. BLOW DOWN TOP DRIVE. Printed 7/6/2015 11:00:17AM 411) North America-ALASKA-BP • Page 48 of 71 Operation Summary Report 's Common Well Name.07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) ' 11 00 - 11:30 0.50 WHSUR P INTI INSTALL WEAR BUSHING -PJSM. INSTALL WEAR BUSHING -CAMERON RUN IN 4 X LOCK DOWN SCREWS. MEASUREMENT=4"ON THE WEAR BUSHING. *WEAR BUSHING - LENGTH=10.5",OD=13 17/16",ID=12 3/16". 11:30 - 12:00 1 0.50 WHSUR P INTI CLEAN/CLEAR RIG FLOOR AREA -CLEAN/CLEAR TOOLS FROM RIG FLOOR AREA. *LOSSES FOR TOUR=5 BBLS. 12:00 - 13:00 1.00 CLEAN N HMAN 6,400.00 INTI INSTALL SHORT ELEVATORS BAILS ON TOP DRIVE _PJSM. -INSTALL SHORT ELEVATORS BAILS ON THE _i TOP DRIVE. 13:00 - 14.00 1.00 CLEAN I N HMAN 6,400.00 INTI ;MOBILIZE CLEAN OUT BHA TOOLS TO RIG i FLOOR -PJSM. I I-MOBILIZE CLEAN OUT BHA TOOLS TO THE `RIG FLOOR. -M/U SAFETY JOINT WITH 4"FOSV AND 4" LIFTER. 14:00 - 16:30 2.50 CLEAN. N HMAN , 6,400.00 INTI i M/U 8 1/2"CLEAN OUT BHA -PJSM. M/U BHA#4 FOR CLEAN OUT RUN PRIOR TO RUNNING 7"LINER . __ RIHTO764' 16:30 - 18:30 2.00 CLEAN , N HMAN ! 6,400.00 INTI RIH WITH 8 1/2"CLEAN OUT BHA TO ABOVE 9 5/8"WINDOW -RIH WITH CLEAN OUT BHA FROM 764'TO 2734'. STOP ABOVE 9 5/8"WINDOW. 18:30 - 20:00 1.50 CLEAN N HMAN 6,400.00 INTI BREAK CIRCULATION AND STAGE UP PUMP RATE BREAK CIRCULATION AND STAGE UP PUMP RATE IN 0.5 BBL INCREMENTS TO A MAX OF 1 550 GPM,1050 PSI. -HOLD PUMP RATE AT 500 GPM DUE TO ' LOSSES INCREASING. -LOST 15 BELS DURING CIRCULATION. _ 20 00 - 22:00 2.00 CLEAN ' N HMAN 6,400.00 j INTI SLIP/CUT DRILL LINE -PJSM. -SLIP/CUT 120'DRILL LINE. !22.00 - 23:00 1.00 CLEAN N HMAN 6,400.00 INTI CALIBRATE BLOCK HEIGHT AND CHECK CROWN-O-MATIC. 23:00 00:00 1.00 CLEAN N HMAN -____ - 6,400.00 i INT1 RIH WITH 8 1/2"CLEAN OUT BHA CONTINUE RIH WITH 8 1/2"CLEAN OUT BHA FROM 2757'TO 3612'. -HOLE SLICK. NO TIGHT SPOTS. LOSSES FOR TOUR=26 BBLS(12 BBLS STATIC LOSSES,10 TRIPPING,4 1CIRCULATING) 5/18/2015 00:00 - 03:00 3.00 , CLEAN N HMAN 6,400.00 1,�INT1 RIH WITH 8 1/2"CLEAN OUT BHA CONTINUE RIH WITH 8 1/2"CLEAN OUT BHA from 3612'to 8548'. -FILL PIPE EVERY 20 STDS. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 49 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 05:30 2.50 CLEAN N HMAN 6,400.00 INTI CIRCULATE ABOVE THE HRZ -BREAK CIRCULATION AND STAGE PUMP RATE UP IN 1/2 BBL INCREMENTS TO 500 GPM,-2400 PSI. -HOLD PUMP RATE AT 500 GPM DUE TO LOSSES INCREASING. -RECIPROCATE PIPE FROM 8548'TO 8643'. -GEOLOGY REPORTS THAT BU SAMPLES ARE ALL HRZ"FINES". -LOST-35 BBLS WHILE CIRCULATING. 05.30 - 06:00 0.50 CLEAN N HMAN 6,400.00 INTI RIH WITH 8 1/2"CLEAN OUT BHA -CONTINUE RIH WITH 8 1/2"CLEAN OUT BHA FROM 8643'TO 9169'. SET 15K DOWN. P/U 40K OVER. 06:00 - 10:00 4.00 CLEAN N HMAN li 6,400.00 INTI 'WORKING THRU TIGHT HOLE PUMP OUT OF HOLE AT 3 BPM,500 PSI,15 ROT,7K TORQUE. -ROTARY STALLED OUT WITH 50K OVERPULL. HOLE PACKING OFF AT 9169',8833'. -WORK THRU SLOWLY AND RE-ESTABLISH CIRCULATION AT 2 BPM,480 PSI. I-RE-ESTABLISH ROTATION AND STAGE RPM :UP TO 60 RPM. RE-ESTABLISH PIPE MOVEMENT UP AND I INCREASE PULLING SPEED TO 25 FPM. POOH ABOVE THE HRZ TO 8643' 10:00 12:30 2.50 CLEAN N HMAN 6,400.00 INTI BREAK CIRCULATION AND STAGE PUMP RATE UP 500 GPM,2330 PSI,80 ROT,6K TORQUE. -RECIPROCATE PIPE FROM 8643'TO 8548'. OBSERVE LARGE INCREASE IN CLAYS AT BOTTOM UP ALONG WITH SAND AND SHALE. 12:30 - 15 30 3.00 CLEAN N HMAN 6,400.00 INTI REAM DOWN WITH TOP DRIVE -REAM DOWN FROM 8643'TO 9403'AT 442 GPM,1870 PSI,100 ROT,6K TORQUE. I-TAG UP AT 9287'WITH 10K DOWN, PRESSURE INCREASED FROM 1870 PSI TO 2240 PSI. -P/U AND WORK THRU. 15:30 - 16 00 0.50 CLEAN N HMAN 6.400.00 INTI REAM DOWN WITH TOP DRIVE -BREAK OUT BTM JOINT ON STD#92. -CONTINUE REAMING DOWN FROM 9403'TO 9425',445 GPM,2060 PSI,80 ROT,7K TORQUE. -ENCOUNTER FILL AT 9425'. -CONTINUE TO REAM DOWN TAKING 5'BITES AND WORKING 30'STROKE BEFORE TAKING ANOTHER 5'BITE. -CONTINUE PROCESS TO 9440'. "OBSERVE INCREASE IN SIZE AND VOLUME I OF UN-GROUND SHALES. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 50 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 ' Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task � Code NPT NPT Depth I Phase Description of Operations I (hr) (usft) — 16:00 - 17:30 1.50 CLEAN N I HMAN 6,400.00 INTI I CBU AT 9440'TO LOWER ECD PRIOR TO 1 ENTERING SAG FORMATION -CBU AT 9440'AT 445 GPM,2060 PSI,100 ROT ' RECIPROCATE PIPE 75'WHILE KEEPING 1 I I INSDIE 8 1/2"BIT PILOT HOLE. -TAG HIGH WITH 8K DOWN WHILE RECIPROCATE PIPE AT 9425'. I I-P/U AND WORK PIPE DOWN TO 9440'. CONTINUE TO OBSERVE INCREASE IN SIZE ' I I AND VOLUME OF UN-GROUND SHALES AT ISHAKERS. 17.30 - 19:30 2.00 CLEAN N HMAN 6,400.00 INTI 1 PUMP HI-VIS SWEEP AND CIRCULATE OUT -PUMP 35 BBLS HI-VIS SWEEP AND CIRCULATE AT 445 GPM,2040 PSI,80 ROT,6K I TORQUE.. I-RECIPROCATE PIPE 75. I -OBSERVE 10%INCREASE IN CUTTINGS AT ' SURFACE. , *OBSERVE SIZE-AND VOLUME OF i UN-GROUND-SHALES IN NORMAL RANGE. 19:30 - 20:00 1 0.50 CLEAN N HMAN 6,400.00 INTI WASH/REAM TO TD 1-WASH/REAM AT 3 BPM,25 ROT FROM 9440' TO 9452'TD. 20:00 22:00 i 2.00 CLEAN N i HMAN 6,400.00 INTI 1,PUMP HI-VIS SWEEP AND CIRCULATE OUT -DISCUSS TRIP TO 9452'TD WITH ODE. I-DECISION MADE TO PUMP ADDITIONAL HI-VIS AND CIRCULATE OUT AT 500 GPM,80 I ROT. OBSERVE<5%INCREASE IN CUTTINGS AT SURFACE. *OBSERVE"FINES"CUTTINGS AT SURFACE. 22:00 - 00:00 2.00 CLEAN N HMAN 6,400.00 INTI WIPER TRIP TO ABOVE HRZ -RECEIVE OCN#5 FROM ODE AND REVIEW ;WITH RIG PERSONNEL. -PJSM. I-PUMP OUT HOLE AT 2 BPM,310 PSI,25-40 'FPM. TAKE 15K OVERPULLAT 9312'. -START ROTATING 25 RPM AND P/U THRU SPOT. -STOP ROTATION AND S/O,P/U SLICK THRU SPOT. CONTINUE PUMPING OUT SLICK AT 2 BPM I AT 25-40 FPM TO 9323'. I LOSSES FOR TOUR=40 BBLS. 5/19/2015 00:00 - 01:30 1.50 CLEAN I N HMAN I 6,400.00 INTI WIPER TRIP TO ABOVE HRZ. I -PJSM. -CONTINUE PUMPING OUT OF HOLE AT 2 I BPM,25-40 FPM FROM 9023'TO 8643'. >WORK THRU WITH ROTARY. STOP ' ROTARY AND PULL AREA SLICK. -CONTINUE POOH SLICK ON ELEVATORS FROM 8643'TO 8263'. 01 30 - 02:00 0.50 CLEAN N HMAN 6,400.00 INTI RIH TO 9,403'TD. -RIH FROM 8263'TO 9403'. HOLE SLICK. Printed 7/6/2015 11 00:17AM 4 North America-ALASKA-BP • Page 51 of 71 ,-„, ,4,,,, ,:,.:,/-.:;;,,,,,?%:‘,1!;,,,,,,,f;,.,,:.:; •% , ,,,'..-.,-;;;•:.-:',?.;.,.,,,-,-.,;:;,:-, ' ' Operation Summary Report Common Well Name 07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 03:30 1.50 CLEAN N HMAN 6,400.00 INTI RIH FROM 9,403'TO 9,452'TD I_AT 9,403',9,428 SET DOWN 15K. ROTATE ! I DOWN THRU AT 25 RPM. STOP ROTARY AND j I I S/O SLICK. � � I-AT 9,444'SET DOWN 15K. ROTATE AT 25. I UNABLE TO WORK THRU. STAGE PUMP I RATE UP TO 500 GPM AND WASH/REAM I !THRU. STOP PUMP/ROTARY AND SIO SLICK. -CONTINUE TO WASH DOWN TO 9,445'. '-TAG 7'OF FILL. -WASH DOWN FROM 9,445'TO 9.452'TD. 03 30 - 10:00 6.50 CLEAN N HMAN 6,400.00 INTI CIRCULATING SWEEPS -CBU:500 GPM AND 2450 PSI -AT BOTTOMS UP PUMP 35 BBLS SWEEP. '-OBSERVE 5%INCREASE IN RE-GROUND CUTTINGS CONSISTING OF SAND/SHALE. I -PUMP 2ND 35 BBLS SWEEP. I-2ND SWEEP STARTED DOWNHOLE PRIOR TO 1ST SWEEP BEING OUT OF HOLE. I-CONTINUE TO CIRCULATE OUT. II*0330 HRS-PERFORM EVALUATION OF MUD I 'TO DETERMINE SOLIDS CONTENT. SOLIDS CONTENT ARE WITHIN NORMAL PARAMETERS FOR MUD WEIGHT. 10.00 - 11:30 1.50 CLEAN N HMAN 6,400.00 INTI SPOT SURGE PILL PRIOR TO PULLING OUT OF HOLE WITH CLEANOUT BHA. I 1 -PJSM TO LAY IN SURGE PILL. I LAY IN PILL FROM 9,452'MD TO 8,548'MD. -POOH 45 FT/MIN,PUMP RATE:2 BPM AND , 270 PSI. -POOH ON ELEVATORS FROM 8,548'MD- 8,263'MD. 1-15 K OVER PULL AT 9,340'MD&8,792'MD. -DECISION MADE TO RUN BACK IN HOLE& VERIFY HOLE CONDITION. 11:30 - 12:30 1.00 CLEAN N HMAN 6,400.00 INTI RUN BACK IN HOLE WITH 8-1/2":CLEANOUT ASSEMBLY. ' -RIH ON ELEVATORS FROM 8,263'MD TO I 9,444'MD. I -NO ISSUES TO 9,444'MD. TAG 5-7K,AT 9,444'MD,8 FT OFF BOTTOM. STAGE UP PUMP RATE IN 1/2 BBLS I INCREMENTS TO 500 GPM. I -WASH DOWN WITH NO ROTATION TO 9,452' MD,TAG BOTTOM WITH 5K WOB. I PUMP 500 GPM,2400 PSI. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP S Page 52 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual t 60.72usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 16:30 4.00 CLEAN I N r HMAN 6,400.00 INTI CIRCULATE OUT SURGE PILL AND SWEEP. CBU AT 167 GPM WITH 450 PSI WHILE RECIPROCATING PIPE. -AT BOTTOMS UP, ALL SURGE PILL OUT OF HOLE. I-PUMP 35 BBLS SWEEP. -OBSERVE SLIGHT INCREASE IN RETURNS, `CONSISTING OF MICROFINE SAND. NO SHALE OBSERVED IN RETURNS. CONTACT ODE,DECISION MADE TO POOH AND RUN 7"LINER. -OBTAIN SLOW PUMP RATES AND FLOW CHECK WELL PRIOR TO PULLING OFF BOTTOM. WELL IS STATIC. 16.30 - 21:30 5.00 CLEAN N HMAN 6,400.00 INTI SPOT SURGE PILL PRIOR TO PULLING OUT OF HOLE WITH CLEANOUT BHA. -PJSM TO LAY IN SURGE PILL AND PULL OUT OF HOLE. -LAY IN PILL FROM 9,452'MD TO 8,548'MD. -POOH 45 FT/MIN,PUMP RATE:2 BPM AND 270 PSI. i-POOH ON ELEVATORS FROM 8,548'MD TO 'WINDOW. -FLOW CHECK AT WINDOW 10 MINS. WELL IS STATIC. 21 30 - 00:00 2.50 CLEAN N HMAN 6,400.00 INTI PJSM,POOH WITH CLEANOUT BHA. -POOH F/2,745'MD T/855'. -FLOW CHECK WELL PRIOR TO PULLING NON SHEARABLES INTO BOPE STACK -WELL IS STATIC. -STAND BACK 4"DP AND 5"HWDP. -LAY DOWN HYD JARS. 24 HR LOSSES:40 BBLS, 10.8 PPG MUD 5/20/2015 00:00 - 01:00 1.00 CASING N HMAN 6,400.00 INTI CONTINUE LAYING DOWN CLEAN OUT BHA. -PJSM AND REVIEW DDI SOP. STAND BACK REMAINING 5'HWDP AND UD REMAINING BHA COMPONENTS TO PIPE SHED. 01:00 01:30 0.50 CASING N HMAN 6,400.00 INTI PREPARE TO RUN 7"26#L-80 VTHC LINER. -PJSM FOR BEAVER SLIDE OPERATIONS. -REMOVE ALL EQUIPMENT NOT NEEDED FOR 7"LINER RUN AND BRING IN EQUIPMENT FOR 7"LINER RUN. 01'30 - 03:30 2.00 CASING N HMAN 6,400.00 INTI RIG UP FLOOR EQUIPMENT FOR RUNNING 7" 26#L-80 VTHC LINER. -PJSM AND MAKE UP WELL CONTROL EQUIPMENT WITH PROPER CROSSOVERS. -INSTALL VOLANT TOOL TO TOP DRIVE WITH BALE EXTENSIONS AND 250 TON SIDE DOOR ELEVATORS. -RIG UP HYDRAULIC TONGS WITH TORQUE TURN EQUIPMENT. *LOSSES TO WELL WHILE MONITORING FROM TRIP TANK ARE±1 BPH. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 53 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual t 60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 05:00 ' 1.50 CASING N HMAN I 6,400.00 INTI RIH WITH 7"26#L-80 VTHC LINER AS PER RUNNING ORDER. PJSM WITH ALL PERSONNEL AND REVIEW ' DDI SOP AND IDENTIFY EXCLUSION ZONES IN PIPE SHED AND ON RIG FLOOR. I-DISCUSS PROPER COMMUNICATION ' , I BETWEEN FLOOR HANDS AND TONG OPERATOR BEFORE TONGS ARE MOVED. I-P/U AND M/U SHOE TRACK WITH BAKER-LOK AND CHECK FLOATS.FLOATS I GOOD. *DRILLER AND COMPETENT INDIVIDUAL VERIFY PROPER SIZE OF HANDLING I , I EQUIPMENT WITH CALIPERS. *WSL,DRILLER,TOOLPUSHER AND BAKER REPRESENTATIVE AGREE ON PIPE COUNT IN I PIPE SHED AND RUNNING ORDER. *LOSSES REMAIN AT±1BPH. *D1 DRILL WITH CRT OF 130 SECONDS 05.00 - 12:00 7.00 CASING N HMAN 6,400 00 INTI 'RUN 7",26#,L-80,VTHC LINER FROM i SURFACE TO WINDOW AT 2,755'MD. i 1-USE JETLUBE SEAL GUARD. ' -TORQUE TURN CONNECTIONS TO 11,950 FT-LBS. -RUN 1 FLOATING CENTRALIZER ON JOINTS 1 1-35. -FILL LINER WITH VOLANT EVERY 10 JOINTS ' AND CIRCULATE FOR 5 MINUTES AFTER STAGING PUMPS UP TO 126 GPM. ' ,-OBTAIN P/U&S/O EVERY 10 JTS. ; I-RIH AT 60 FT/MIN INSIDE CASING WHILE ,MONITORING DISPLACEMENT FROM TRIP TANK. -MUD WEIGHT 10.8 PPG IN,10.8 PPG OUT. *LOSSES REMAIN AT±1 BPH. 12:00 12:30 0.50 CASING N HMAN 6,400.00 INTI I CIRCULATE BEFORE EXITING WINDOWAT 12,755'MD. -CIRCULATE 1.5X LINER VOLUME AT 127 GPM -r V ITH 220 PSI. 12:30 22:00 9.50 CASING N HMAN 6,400.00 INTI RUN 7"26#L-80 VTHC LINER INTO OPEN HOLE F/2,755'MD T/6,455'MD. -BREAK CIRCULATION EVERY 400'AT 127 GPM FOR 5 MINUTES AFTER TOPPING OFF 1 PIPE AND STAGING PUMPS UP IN 1/2 BBL I INCREMENTS TO 127 GPM. 1 -OBTAIN PU/SO WEIGHTS EVERY 10 JTS -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT MUD WEIGHT:10.8PPG IN,10.8 PPG OUT MUD LOSSES WHILE RIH:-1 BBLS/HR 22:00 22:30 0.50 CASING P INTI RIG DOWN VOLANT TOOL -R/D TOOL AT 6,458'MD(JT#154) -CONTINUE IN HOLE WITH 7"LINER '-RIH FROM 6458'MD TO 6783'MD -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT -MUD WEIGHT:10.8PPG IN,10.8 PPG OUT -MUD LOSSES WHILE RIH:-1 BBLS/HR Printed 7/6/2015 11.00.17AM • North America-ALASKA-BP r Page 54 of 71 "` % Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 23:30 ' 1.00 CASING P INTI PJSM MAKE UP LINER TOP PACKER ASSEMBLY WITH BOT -CHANGE OUT ELEVATORS AND LAY DOWN 4'BALE EXTENSIONS I-CONFIRM ID'S&OD'S OF ELEVATORS& TOOL JTS MAKE UP 7"X 9-5/8"BOT FLEX LOCK LINER 1 ' 'HANGER AND ZXP LINER TOP PACKER ASSEMBLY PER IBAKER REP -P/U:223K,S/O:170 K 23:30 - 00:00 0.50 CASING N DPRB 3,450.00 , INTI I RUN IN HOLE WITH LINER TOP PACKER I-MAKE UP 1 JOINT OF 5"HWDP TO 5'DP PUP ON TOP OF HANGER ASSEMBLY I I I-PICK UP OUT OF SLIPS,RIH 3 FT AND i t ANCOUNTER HARD TAG -ATTEMPT TO WORK FREE 24 HR LOSSES=23 BBLS 10.8 PPG MUD 5/21/2015 1 00:00 - 02:30 2.50 CASING N DPRB I 3,450.00 INTI 7"26#LINER AND LINER TOP PACKER I ) ASSEMBLY HUNG UP. -MAKE UP 1 JOINT OF 5"HWDP TO 5'DP PUP ON TOP OF HANGER ASSEMBLY. '-PICK UP OUT OF SLIPS,RIH 3 FT AND I I ENCOUNTER HARD TAG. -ATTEMPT TO WORK FREE BY INCREASING 1 'P/U AND SLACK OFF. { -PICK UP 50 K OVER,8"STRETCH AT SURFACE. I DISCUSS OPTIONS WITH SUPERINTENDANT I AND ODE. -PICK UP 100 K OVER,18"STRETCH. 18"STRETCH INDICATES POSSIBLE DIFFERENTIAL STICKING AT 3,450'MD. ' -SUPERINTENDANT ON LOCATION. -INCREASE PICK UP TO 175K OVER. -DECREASE SLACK OFF TO 90 K. -PIPE FREE,MAKE UP SECOND OF 2 SINGLES OF 5"HWDP&CONTINUE RUNNING IN HOLE. 02:30 05:30 3.00 CASING P I INTI RIH WITH 7",26#,L-80,VTHC LINER FROM , 6,800'MD TO 9,350'MD. RIH ON ELEVATORS WITH 6 STANDS OF 5" HWDP FROM DERRICK AT 30 FT/MIN. -CONTINUE RIH WITH 20 STANDS 4"DP I !FROM DERRICK. -WASH DOWN EVERY 4TH STAND AT 3 BPM AND 370 PSI UNTIL-150'ABOVE THRZ. -P/U=282K,S/0=181K AT 8,510'MD(-150' ABOVE THRZ). -MONITOR WELL VIA TRIP TANK:PROPER ' DISPLACEMENT. -MUD WEIGHT 10.8 PPG IN,10.8 PPG. I Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 55 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 06:00 0.50 CEMT P INTI MAKE UP BOT DUAL PLUG DROP/BALL ! I DROP CEMENT HEAD. -RUN IN HOLE TO 9,350'MD,PICK UP 4"DP 1PUPS,AND 2 MORE JTS OF 4"DP T/9,425'. �-PICK UP AND MAKE UP BOT CEMENT HEAD. ESTABLISH CIRCULATION AND STAGE PUMP RATE UP TO 125 GPM WITH 550 PSI. WASH DOWN 7"LINER F/9,425'T/9,450'. 06:00 - 13:00 7.00 CEMT P INTI PJSM LAND 7"VTHC LINER -OBTAIN MARKS ON FINAL JOINT OF 4"DP I FOR PICK UP WEIGHT AND TD TO WORK PIPE STRETCH -STAGE UP PUMPS IN 0.5 BBL INCREMENTS BEFORE CUTTING MUD WEIGHT -63 GPM,470 PSI I I-84 GPM, 510 PSI 105 GPM,580 PSI '-126 GPM,640 PSI -147 GPM,660 PSI -168 GPM,700 PSI I-189PM 750 PSI I S I-210 GPM,800 PSI ICP,700 PSI FCP BEGIN CONDITIONING MUD WHILE WORKING •r3 FT PIPE STRETCH "-300 GPM,1060 PSI -CONDITION MUD TO 10.5 PPG,12 PV,20 YP 13:00 - 15:00 2.00 CEMT P INTI PRESSURE TEST SLB CEMENT HARDLINE TO , RIG FLOOR -UTILIZE PRESSURE TESTING CHECKLIST I-LEAK IN RIG SURFACE LINES DISCOVERED I-LINE UP AND CONTINUE CIRCULATION WHILE REPAIR LEAKING CONNECTION TEST SLB CEMENT LINES TO RIG FLOOR. -250 PSI LOW/4500 PSI HIGH FOR 5 MIN, GOOD LEAK TIGHT TEST. 15:00 - 17:00 2.00 CEMT P INTI 1PJSM SET LINER HANGER PER BOT REP I-ESTABLISH CIRCU:LATION AND DROP 1-1/2" BALL ,-PUMP BALL DOWN AT 78 GPM&310 PSI -BALL ON SEAT,PRESSURE UP TO 2900 PSI I TO SET LIINER HANGER -SET 50 K DOWN TO CONFIRM LINER HANGER SET -PRESSURE UP TO 4000 PSI TO RELEASE RUNNING TOOL AND SHEAR RUPTURE DISC IN DOBS I I -PICK UP AND CONFIRM RELEASE ! -PRESSURE UP 500 PSI TO RELEASE BALL FROM DOBS I -STAGE UP MUD PUMPS AND CIRCULATE AT 298 GPM,1000 PSI DURING CEMENT BATCH UP Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 56 of 71 Operation Summary Report Common Well Name.07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00'00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ! NPT Depth I Phase Description of Operations (hr) (usft) 17:00 - 18:30 1.50 CEMT P INTI CEMENT 7"26#VTI-IC LINER AS FOLLOWS: PUMP 45 BBLS OF 11.0 PPG MUDPUSH II SPACER AT 5.0 BPM,560 PSI WITH SLB PUMPS -DROP 1ST WIPER DART -PUMP 67.7 BBLS OF 15.8 PPG CLASS G TAIL 1 t i WITH GASBLOK©5 BPM,630 PSI EXCESS VOLUME 40%(YIELD 1.17 CU.FT/SK) WITH SLB PUMPS -DROP 2ND WIPER DART !PERFORM 10.5 PPG LSND MUD DISPLACEMENT WITH CEMENT PUMPS -23 BBLS DISPLACED AT 7 BPM:ICP 170 PSI, FCP 540 PSI -SLOW RATE UNTIL DART LATCH UP CONFIRMED -10 BBLS DISPLACED AT 3 BPM: 1-242 BBLS DISPLACED AT 7 BPM:ICP 560 PSI, FCP 1198 PSI- '-10 BBLS DISPLACED AT 2 BPM,ICP 530 PSI !BUMP PLUG AT 285.4 BBLS DISPLACED AND 1135 PSI -HOLD PRESSURE AT 1135 PSI CHECK FLOATS-HOLDING,1.1 BBL BLED BACK -CEMENT IN PLACE: 18:22 HRS DISPLACEMENT FLUID:10.5 PPG LSND TOTAL DISPLACEMENT VOLUME 285.4 BBLS 0 LOSSES THROUGHOUT CEMENT JOB 18.30 - 20 30 2.00 CASING P INTI PJSM WITH BOT TO SET PACKER 1-RIG DOWN AND LAY DOWN CEMENT HEAD -PICK UP 5 FT TO EXPOSE DOG SUBS -SLACK OFF 50K ON LINER TOP PACKER -P/U TO UP WEIGHT&ROTATE 15 RPM, SLACK OFF 1-SET DOWN 2 TIMES TO CONFIRM ZXP PACKER SET PRESSURE UP 500 PSI,PULLING PACK OFF I UP AND OBSERVE PRESSURE DROP -BRING ON PUMPS TO 126 GPM,110 PSI AND I INCREASE TO 336 GPM AND 460 PSI -WASH OUT TIE BACK SLEEVEAND PULL RUNNING TOOLS OUT OF LINER TOP -CIRCULATE 2 BU 460 GPM,610 PSI RACK BACK 1 STAND AND LAY DOWN 2 DP PUP JOINTS 20:30 - 00:00 3.50 CASING N WAIT 2,630.00 INTI PREPARE TO SHUT IN WELL TO WAIT ON WEATHER -KICK WHILE TRIPPING DRILL -P/U 106K,S/O 107K, -CIRCULATE FOR 3 MINS,120 GPM,118 PSI -INSTALL FOSV,CLOSE ANNULAR AND VBRS i I ON 4"DP PER OCN#6 WELL SHUT IN DUE TO FLOODING OVER ROADS -WAIT ON APPROVAL TO RESUME OPERATIONS 24 HR LOSSES:25.5 BBLS Printed 7/6/2015 11:00:17AM North America-ALASKA-BP • Page 57 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) I 5/22/2015 00:00 - 14:30 14.50 CASING N WAIT 2,630.00 INTI WELL SHUT IN, WAIT ON WEATHER FOSV INSTALLED I-ANNULAR AND VBR CLOSED ON 4"DP PER OCN#6 I I WELL SHUT IN DUE TO FLOODING OVER ROADS -WAIT ON APPROVAL TO RESUME OPERATIONS 14:30 - 20:30 6.00 CASING P INTI APPROVAL GIVEN TO PROCEED WITH OPERATIONS FROM ODE&WTL I PJSM,WSL DISCUSS PLAN TO OPEN WELL OPEN FOSV TO MUD MANIFOLD -OPEN BLEEDER,VERIFY NO FLOW FROM DP -OPEN LOWER VBRS TO OPEN HCR CHOKE, VERIFY NO PRESSURE UNDER ANNULAR -OPEN CHOKE TO MGS AND VERIFY NO FLOW IN PITS FROM MGS DRAIN OPEN ANNULAR PREVENTER PULL OUT OF HOLE ON ELEVATORS WITH LINER RUNNING TOOL -MONITOR WELL FOR 10 MINUTES:WELL STATIC -PULL OUT OF HOLE FROM 2,630'MD TO SURFACE -LAY DOWN 5"HWDP,STAND BACK 4"DP LAY DOWN LINER RUNNING TOOL PER BAKER REP CLEAN AND CLEAR RIG FLOOR MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 20:30 - 22.30 2.00 CASING P INTI PJSM,MIT 7"L-80 26#LINER&BOT ZXP LINER TOP PACKER -PRESSURE TEST 250 PSI LOW FOR 5 CHARTED MINS&3500 PSI HIGH FOR 30 CHARTED MINS -CONFIRM VALVE ALIGNMENT PRIOR TO TEST -PUMPED 4 STKS(0.5 BBLS)TO 250 PSI FOR 5 CHARTED MINS -PUMPED 59 STKS(5.7 BBLS)TO 3710 PSI FOR 30 CHARTED MINUTES. -20 PSI LOST IN 1ST 15 MINS -10 PSI LOST IN 2ND 15 MINS -BLEED OFF PRESSURE,BLED BACK 5.3 BBLS MIT MEETS BP STP CRT-AK-10-45 CRITERIA -RECEIVED PERMISSION TO PROCEED FROM WTL BLOW DOWN LINES -RIG DOWN TEST EQUIPMENT SEE ATTACHMENTS Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP * Page 58 of 71 Operation Summary Report " f Common Well Name 07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UW:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code '', NPT NPT Depth Phase Description of Operations (hr) (usft) — - _-- — 22:30 00:00 1.50 BOPSUR P INTI PJSM,CHANGE OUT UPPER PIPE RAMS FROM 7"PIPE RAMS TO 2-7/8"X 5-1/2"VBRS -DRAIN STACK PULL WEAR RING MAKE UP AND RIH WITH TEST PLUG -CAMERON REP RILDS 24 HR LOSSES:0 BBLS 5/23/2015 00:00 04:00 4.00 BOPSUR P INTI I CHANGE OUT UPPER PIPE RAMS FROM 7" PIPE RAMS TO 2-7/8"X 5-1/2"VBRS -CLOSE BLIND SHEARS -DE-ENERGIZE ACCUMULATOR i I I -CHANGE OUT RAMS 04:00 - 05:30 1.50 BOPSUR P INTI PJSM TEST UPPER 2-7/8"X 5"VBRS -MAKE UP TEST JOINT&TEST PLUG 1-FILL STACK 1-PRESSURE TEST 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINS EACH 1-TEST WITH 4"AND 4-1/2"TEST JOINTS FUNCTION TEST ALL BOPE COMPONENTS -BLEED OFF PRESSURE BLOW DOWN AND RIG DOWN TEST EQUIPMENT INSTALL 9-1/4"I.D.WEAR RING -STAGE BHA COMPONENTS TO RIG FLOOR FOR M/U 6-1/8"DRILLING ASSEMBLY 05:30 - 08.30 3.00 CASING P INTI PJSM MAKE UP 6-1/8"DRILLING ASSEMBLY, BHA#5 DISCUSS HAZARDS INVOLVED WITH LOADING SOURCE MAKE PROPER NOTIFICATIONS TO KEEP I FLOOR&CELLAR CLEAR -MAKE UP BHA PER SLB -TEST ARCHER TOOL IN TABLE LOAD SOURCE PER MWD MAKE UP REMAINDER OF BHA 08:30 - 18:30 10.00 CASING P INTI RUN IN HOLE WITH 6-1/8"DRILLING ASSEMBLY,BHA#5 -6-1/8"PDC BIT,4-3/4"RSS, FLEX COLLAR, E-MAG RECIEVER,IMPULSE MWD,IN LINE ( STABILIZER, ADNVISION 475,(3)FLEX COLLAR,FLOAT SUB,CROSSOVER SUB,(144 JTS)4"DP,(7 JTS)4"HWDP,4-3/4"HYD JARS -OAL OF BHA=179.94' RIH FROM 180'MD TO 9300'MD -RIH ON ELEVATORS WITH 4"DP FROM PIPE SHED SHALLOW TEST TOOLS AT 1,581' 200 GPM AND 940 PSI BREAK CIRCULATION EVERY 15 STANDS, 200 GPM,1200 PSI,20 RPM -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT WELL 02-26 SHUT IN DUE TO CLOSE APPROACH AT 10:30 AM 5-23-15 Printed 7/6/2015 11:00:17AM North America-ALASKA-BP • Page 59 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 118:30 - 19:30 1.00 CASING P INTI TAG TOP OF LANDING COLLAR RUN IN HOLE WITH TO 9,300'MD ESTABLISH PARAMETERS -P/U 223 K,S/O 155 K PUMP AT 250 GPM,1750 PSI -TAG 10 K DO WN AT 9,361'MD r i PICK UP AND LAY DOWN LAST JOINT ON i STAND#92 PREPARE TO SLIPE AND CUT DRILL LINE 19 30 - 21:30 2.00 CASING P INTI CUT AND SLIP DRILLING LINE -PJSM TO REVIEW PROCEDURE -CUT—60'OF DRILL LINE,9 WRAPS 21'30 00:00 2.50 CASING P INTI PJSM DISPLACE TO 8.5 PPG FLO-PRO MUD -FINALIZE FLUID TRANSFER PERMITS WITH 3RD PARTY -PUMP 40 BBL OF 10.5 PPG HI-VIS SPACER J -DISPLACE WELL TO 8.5 PPG FLO-PRO -PUMP:220 GPM,1920 PSI -VOLUME TRACK BBL IN=BBL OUT 24 HR LOSSES:0 BBLS 5/24/2015 00:00 - 01:30 i 1.50 1 CASING P INTI :DISPLACE TO 8.5 PPG FLO-PRO MUD DISPLACE WELL TO 8.5 PPG FLO-PRO -PUMP:220 GPM,1920 PSI -VOLUME TRACK BBL IN=BBL OUT -CONFIRM GOOD 8.5 PPG FLO-PRO ALL THE WAY AROUND SHUT DOWN PUMPS,BLEED OFF ,PRESSURE CONDUCT 30 MINUTE FLOW CHECK FOR NEGATIVE TEST ON 7"LINER LAP RECEIVE APPROVAL FROM WTL TO CONTINUE WITH OPERATIONS I SIM-OPS:REPLACE BRAKE BANDS IN DRAWWORKS 01:30 - 04:00 2.50 CASING P INTI CLEAN PITS TO TAKE ON NEW 8.5 PPG FLO-PRO SIM-OPS WHILE CLEANING PITS FINISH REPLACING BRAKE BANDS 04:00 - 08:30 4.50 CASING P INTI INSPECT SAVER SUB -SAVER SUB HAS SHARP EDGED THREADS. -THREAD GAUGE SHOWS GREATER THAN 1/16"GAP. -PJSM TO CHANGE OUT SAVER SUB. -INSTALL NEW SAVER SUB. -CALIBRATE BLOCKS&HOOK LOAD. -CALIBRATE BLOCK HEIGHT WITH SLB MWD. -CHECK CROWN SAVER. 08:30 - 17:00 8.50 1 CASING P INTI DRILL 6-1/2"SHOE TRACK F/9,360'MD TO 9,452'MD(8,394'TVD) 240 GPM,1460 PSI ON,1450 PSI OFF. -60 RPM,3-5K TORQUE ON,3K TORQUE OFF. PIW 205K,SOW 165K,ROT 182K,WOB 10K. -BACKREAM 30 FT PRIOR TO EVERY CONNECTION. -MW 8.5 PPG IN,8.5 PPG OUT. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 60 of 71 Operation Summary Report ,,o)„*,,y ;; , , ,#;,;-» Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 19:00 2.00 DRILL P PROD1 DRILL OUT CEMENT AND SHOE TRACK PLUS 23'NEW HOLE DRILL TO 9,475'MD,8,487'TVD -240 GPM 1460 PSI ON,1450 OFF i-60 RPM 3-5 K TORQUE ON,3 K OFF -P/U 205K,S/O 165K,ROT 182K 10-12KWOB MUD WEIGHT IN&OUT:8.5 PPG 119:00 - 20:30 1.50 DRILL P PROD1 CIRCULATE BOTTOMS UP 1-PULL BACK TO 7"SHOE FROM 9,575'MD TO 9,430'MD -P/U 200 K,S/O 165 K -PUMPAT 255 GPM,1530 PSI 20:30 - 21:30 1.00 , DRILL P PROD1 RIG UP AND PERFORM FIT MUD WEIGHT:8.5 PPG 7"CASING SHOE:9,450'MD,8,466'TVD -PUMP TO 730 PSI -FIT EMW:10.1 PPG -RECEIVE ODE APPROVAL TO CONTINUE -SEE ATTACHED CHART IBLEED DOWN TEST EQUIPMENT 21:30 - 00:00 2.50 DRILL P _ PROD1 j DRILL 6-1/8"PRODUCTION HOLE FROM 9,475' iMDTO9,525'MD -RUN BACK IN HOLE FROM 9,430'MD TO 9,475'MD -260 GPM 1700 PSI ON,1650 OFF -100 RPM 6-8K TORQUE ON,4-6K OFF WOB 10K -P/U 210K,5/0 168K,ROT 183K -SURVEY EVERY 30 FT I MUD WEIGHT IN&OUT:8.5 PPG ACTUAL ROT TIME:2.2 HRS ACTUAL SLIDE TIME:0.0 HRS 1 TOTAL JAR TIME:2.2 HRS f i 24 HR LOSSES:0 BBLS 5/25/2015 00:00 - 06:00 6.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 9,525' MD TO 9,700'MD -260 GPM 1670 PSI ON,1600 OFF. 100 RPM 6-10K TORQUE ON,4-6K OFF. WOB 10K. -P/U 210K,S/O 168K,ROT 183K. SURVEY EVERY 30 FT. MUD WEIGHT IN&OUT:8.5 PPG 06:00 - 12:00 6.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 9,700' MD TO 9,900'MD(8,816'TVD) -260 GPM 1760 PSI ON,1720 OFF. -80 RPM 11 K TORQUE ON, 9 K OFF. -WOB 8K I-P/U 214K,S/0 168K,ROT 184K. -SURVEY EVERY 30 FT. i MUD WEIGHT IN&OUT:8.5 PPG Printed 7/6/2015 11:00 17AM • North America-ALASKA-BP • Page 61 of 71 Operation Summary Report r Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date 4/24/2015 End Date.6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 9,900' MD TO 10,284'MD(9,013'TVD) -260 GPM 1790 PSI ON,1720 OFF. 100 RPM 5 K TORQUE ON,4K OFF. WOB 10K. -P/U 222K,S/O 178K,ROT 185K. -SURVEY EVERY 30 FT. MUD WEIGHT IN&OUT:8.5 PPG ACTUAL ROT TIME:9.29 HRS ACTUAL SLIDE TIME:0.0 HRS 1 TOTAL JAR TIME:20.26 HRS 24 HR LOSSES:20 BBLS 8.5 PPG FLO-PRO 5/26/2015 00:00 - 01:30 1.50 DRILL P PROD1 !DRILL 6-1/8"PRODUCTION HOLE FROM 110,284'MD T/10,357'MD. -260 GPM 1760 PSI ON,1740 OFF. -100 RPM 5 K TORQUE ON,4K OFF. -WOB 10K. -P/U 222K,S/O 178K,ROT 185K. -SURVEY EVERY 30 FT. MUD WEIGHT IN&OUT:8.5 PPG AT 10,357'MD(9,030'TVD)CBU,LOOKING I FOR TOP OF HOT. DRILL 5 FT TO 10,362'MD(9,031'TVD),CBU AND CHECK SAMPLES. CONTINUE DRILLING IN 5 FT INCREMENTS LOOKING FOR TOP HOT. 4.00 DRILL P ._- - —_ — 01:30 OS 30 � PROD1 'CIRCULATE BOTTOMS UP X1 FOR SAMPLE. -DRILL F/10,356'MD T/10,361'MD. CBU X1. I-DRILL F/10,361 MD T/10,366'MD. CBU X1. -260 GPM,1760 PSI ON 1740 PSI OFF. -100 RPM,4-5K TORQUE ON,3-4K TORQUE OFF. P/U 222K,S/O 178K,ROT 185K. MUD WEIGHT IN&OUT 8.5 PPG. 05 30 - 06:00 0.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/10,366' MD T/10,393'MD. -260 GPM,1760 PSI ON 1740 PSI OFF. -100 RPM,4-5K TOQUE ON 3-4K TORQUE OFF. -WOB 10K. -P/U 222K,S/O 178K,ROT 185K. -MUD WEIGHT IN&OUT 8.5 PPG. 06:00 - 07:30 1.50 DRILL P PROD1 CIRCULATE BOTTOMS UP X1 FOR SAMPLE -260 GPM=1740 PSI,100 SPM=4K TORQUE. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 62 of 71 Operation Summary Report ` Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 12:00 4.50 DRILL P PROD1 1DRILL 6-1/8"PRODUCTION HOLE F/10,393' I MD T/10,503'MD I-260 GPM,1760 PSI ON 1740 PSI OFF. I-100 RPM,4-5K TOQUE ON 3-4K TORQUE OFF. -WOB 10K P/U 222K,S/O 178K,ROT 185K. MUD WEIGHT IN&OUT 8.5 PPG. -SCRATCH AND SNIFF TO LOCATE TOP OF HOT F/10,357'MD.T/10,440'MD. -TOP OF HOT OBSERVED WITH TAR IN I SAMPLE F/10,440'MD SAMPLE. -CONFIRM PLAN WITH GEO AND DD ON INVERTING WELLAND ACHIEVING OBJECTIVE. 12:00 - 19:30 7.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/10,503' MD T/10,808'MD. -260 GPM,1900 PSI ON,1800 PSI OFF. 100 RPM,5-6K TORQUE ON,3-4K TORQUE OFF. -WOB 10-20K. -P/U 220K,S/O 172K,ROT 188K. -MUD WEIGHT IN&OUT 8.5PPG. `IDENTIFY TOP OF HOT WHILE INVERTING WELLAND ROP AT 10 FPH AT 10,417'MD, 19,011'TVD AND 8,926'TVDSS. 19:30 - 20:00 0.50 DRILL P PROD1 FLOW CHECK AT 10,808'MD. -OBSERVED DRILLING BREAK. -STOPPED DRILLING TO FLOW CHECK. NOTED FLUID LOSS STATIC 15 BBL/HR, DYNAMIC 23 BBL/HR. -CONTACTED DRILLING SUPERINTENDENT, W I TL,AND ODE. - INSTRUCTED TO CONTINUE DRILLING WITH PERMISSION TO ADD LCM IF NECESSARY. 20:00 - 00:00 4.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/10,808' MD T/10,980'MD. -260 GPM,1900 PSI ON,1830 PSI OFF. -120 RPM,6-8K TORQUE ON,3-5K TORQUE OFF. -WOB 10-15K. -P/U 213K,S/O 173K,ROT 183K. -SURVEY EVERY 30FT. -ACTUAL ROTATE TIME=6.95HRS. -JARS TIME=31.64HRS. -BACKREAM 30 FT PRIOR TO CONNECTIONS. -MUD WEIGHT IN 8.6PPG OUT 8.7PPG. *CURRENT LOSSES TO FORMATION 18-21 BPH. Printed 7/6/2015 11 00 17AM • North America-ALASKA-BP Page 63 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:OOAM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual t60.72usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft)— - 5/27/2015 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/10,980'MD T/11,642'MD. 260 GPM 1900 PSI ON,1830 OFF. 120 RPM 6-8K TORQUE ON,3-5K OFF. WOB 10-12K. P/U 220K,S/O 161K,ROT 185K. -ACTUAL ROTATE TIME 9.85 HRS. -SURVEY EVERY 90 FT. 1-BACKREAM 30 FT.PRIOR TO CONNECTIONS AS HOLE CONDITION AND MUD PROPERTIES DICTATE. MUD WEIGHT IN 8.6 PPG OUT 8.7 PPG. *FIRE DRILL WITH CRT OF 100 SEC. 12.00 - 00:00 12.00 DRILL P PROD1 j DRILL 6-1/8"PRODUCTION HOLE F/11,642'MD T/12,401'MD. -260 GPM 2020 PSI ON,1980 OFF. 120 RPM 8-10K TORQUE ON,6-8K OFF. -WOB 8-12K. -P/U 225K,S/O 158K,ROT 185K. ACTUAL ROTATE TIME 9.5 HRS. I-SURVEY EVERY 90 FT. BACKREAM 30 FT.PRIOR TO CONNECTIONS 'AS HOLE CONDITION AND MUD PROPERTIES DICTATE. MUD WEIGHT IN 8.7 PPG OUT 8.7 PPG. *SPILL DRILL WITH CRT OF 79 SEC. *CURRENT LOSSES TO FORMATION AT 7 TO 9 BPH. 5/28/2015 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/12,401'MD T/12,781'MD. 9047'TVD. -260 GPM 2020 PSI ON,1980 PSI.OFF. 120 RPM 8-10K TORQUE ON,5-7K OFF. -WOB 8-12K. -P/U 218K,5/0 158K,ROT 183K. -SURVEY EVERY 90 FT.AND 30'WHEN DLS GREATER THAN 5*/100'. ACTUAL ROTATE TIME 9.03 HRS. BACKREAM 30 FT.PRIOR TO CONNECTIONS AS HOLE CONDITION AND MUD PROPERTIES DICTATE. -MUD WEIGHT IN 8.6 PPG OUT 8.7 PPG. *SPR'S OBTAINED AT 12,779'MD. *DRILL AHEAD IN THE IVISHAK ZONE-2A FORMATION. KEEPING ABOVE THE'HOT'. *HELD A SPILL DRILL.RESPONSE TIME 1 MIN 35 SECONDS.GOOD PARTICIPATION FROM THE CREW. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 64 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:OOAM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 DRILL P PROD1 !DRILL 6-1/8"PRODUCTION HOLE F/12,781'MD T/13,370'MD. 9044'TVD. -260 GPM 1980 PSI ON,1950 OFF. 110 RPM 7-8K TORQUE ON,5-6K OFF. WOB 8-12K. -P/U 225K,S/0 178K,ROT 183K, -SURVEY EVERY 90 FT.AND 30'WHEN DLS GREATER THAN 5°/100'. -ACTUAL ROTATE TIME 9.28 HRS. BACKREAM 30 FT.PRIOR TO CONNECTIONS AS HOLE CONDITION AND MUD PROPERTIES DICTATE. -MUD WEIGHT IN 8.7 PPG OUT 8.7 PPG. *SPR'S OBTAINED AT 13,161'MD. I*SWAPPED OUT 189 BBL 8.7 PPG FLO PRO MUD FOR 8.5 PPG NEW FLO PRO WHILE I DRILLING. **AOGCC NOTICE OF UPCOMING BOP TEST SENT AT 15:1-7 HRS 5-28-15. RESPONSE FROM L.GRIMALDI THAT WITNESSING THE TEST WILL BE WAIVED. *CURRENT LOSSES TO FORMATION AT 6 TO .9 BPH. 5/29/2015 I 00:00 - 02:30 2.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 13,370 MD TO 13,445'MD(9,044'TVD) -262 GPM 2010 PSI ON,2000 OFF. -120 RPM 6K TORQUE ON,6K OFF. -WOB 4-15K. P/U 222K,S/O 159K,ROT 182K, SURVEY EVERY 90 FT.AND 30'WHEN DLS GREATER THAN 5°/100'. -ACTUAL ROTATE TIME 2 HRS. BACKREAM 30 FT.PRIOR TO CONNECTIONS AS HOLE CONDITION AND MUD PROPERTIES DICTATE. MUD WEIGHT IN 8.7 PPG OUT 8.7 PPG. 02:30 - 03:00 0.50 DRILL N WAIT 13,445.00 PROD1 CONFIRM TRAJECTORY OF DD PLAN APPROVED BEFORE CONTINUING. -WSL NOTIFIED THAT DD TRAJECTORY OF DRILLING AHEAD PLACES THE WELL OUT OF THE DRILLER'S POLYGON BY 3 TO 5 FEET BUT STAY'S WITHIN THE GEOLOGY POLYGON. -MAKE PROPER NOTIFICATIONS TO TOWN TEAM AND FIELD SUPERINTENDENT. -NWD CONFIRMS NO ADDITIONAL RISKS OF COLLISION AND GIVES APPROVAL TO PROCEED. ETL,ODE AND FIELD SUPERINTENDENT AGREE TO DRILL AHEAD WITHOUT CROSSING THE GEOLOGIST POLYGON. **SLB TOWN CONFIRMED THAT DRILLING DID NOT EXIT DRILLERS POLYGON. Printed 7/6/2015 11 00:17AM • North America-ALASKA-BP Page 65 of 71 Operation Summary Report ,. Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date.6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 12:00 9.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 113,445'MD TO 13,920'MD(9,028'TVD) -260 GPM,2020 PSI ON,1990 OFF. -120 RPM,6-8K TORQUE ON,4-6K TORQUE OFF. -WOB 5-10K. -P/U 225K,S/O 160K,ROT 180K SURVEY EVERY 90 FT AND 30'WHEN DLS GREATER THAN 5°/100'. I-ACTUAL ROTATE TIME 6.4 HRS. -BACKREAM 30 FT PRIOR TO CONNECTIONS AS HOLE CONDITION AND MUD PROPERTIES DICTATE. -MUD WEIGHT IN 8.7 PPG,OUT 8.7 PPG. *SPR'S OBTAINED AT 13,920'MD. *PERFORM DUMP AND DILUTION OF 100 BBLS.FROM ACTIVE PITS AND ADD 100 BBLS. FROM RESERVE PIT @ 03:30. *LOSS RATE TO FORMATION AT 6 TO 9 BPH (DYNAMIC). 12:00 - 18:30 6.50 DRILL I P PROD1- DRILL6-1/8"PRODUCTION HOLE FROM 13,920'MD TO 14,179' 260 GPM,2090 PSI ON,1990 OFF. -120 RPM,6-8K TORQUE ON,4-6K TORQUE OFF. WOB 10-14K. P/U 224K,S/O 158K,ROT 180K 1-SURVEY EVERY 90 FT AND 30'WHEN DLS GREATER THAN 5°/100'. -ACTUAL ROTATE TIME 5.86 HRS. BACKREAM 30 FT PRIOR TO CONNECTIONS AS HOLE CONDITION AND MUD PROPERTIES DICTATE. -MUD WEIGHT IN 8.7 PPG,OUT 8.7 PPG. , I *LOSS RATE TO FORMATION AT 10 BPH (DYNAMIC). 18:30 - 21:30 3.00 DRILL P PROD1 EVALUATE DIRECTIONAL PLAN FOR EXTENSION PAST CURRENT TC PLOT SCAN TO REACH PGOC WITH LOGGING TOOLS. -DISCUSS WITH SLB DD,GEOLOGISTS,ODE, WSL WAIT FOR NEW TC PLOT FROM SLB TO DRILL PAST PLANNED TD OF 14,240'MD. -260 GPM,2090 PSI ON,1990 OFF. -120 RPM,6-8K TORQUE ON,4-6K TORQUE OFF. -RECIPROCATE PIPE 60'WHILE CIRCULATING AND ROTATING *RECEIVE NEW TC PLOT WITH A NEW AC SCAN TO 14,740'MD. *RECEIVE APPROVAL FROM GEOLOGISTS AND ODE TO DRILL PAST END OF DRILLERS AND GEO POLYGON TO NEW TD. Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP 5 Page 66 of 71 �, ` Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) ! Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site.PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12.00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations r) 00:00 2.50 DRILL P (usft) PROD1 ~DRILL 6-1/8"PRODUCTION HOLE FROM i 21:30 14,179'MD TO 14,248'(8,934'TVD) -260 GPM,2090 PSI ON,1990 OFF. -120 RPM,6-8K TORQUE ON,4-6K TORQUE OFF. WOB 10-14K. -P/U 224K,S/O 158K,ROT 180K j-SURVEY EVERY 90 FT AND 30'WHEN DLS I GREATER THAN 5°/100'. ACTUAL ROTATE TIME 5.86 HRS. BACKREAM 30 FT PRIOR TO CONNECTIONS AS HOLE CONDITION AND MUD PROPERTIES DICTATE. MUD WEIGHT IN 8.7 PPG,OUT 8.7 PPG. *SPR'S OBTAINED AT 14,301'MD. *LOSS RATE TO FORMATION AT 10 BPH (DYNAMIC). *TOTAL LOSSES TO FORMATION LAST 24 i rt HRS=150 BBLS 5/30/2015 I 00:00 - 02:30 2.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 14,248'MD TO 14,396'MD(8,885'TVD) • 1260 GPM,2090 PSI ON,2060 OFF. -120 RPM,9-10K TORQUE ON,6K TORQUE OFF. -WOB 10-13K. P/U 224K,S/O 153K,ROT 180K -SURVEY EVERY 90 FT AND 30'WHEN DLS GREATER THAN 5°/100'. BACKREAM 30 FT PRIOR TO CONNECTIONS AS HOLE CONDITION AND MUD PROPERTIES DICTATE. -MUD WEIGHT IN 8.7 PPG,OUT 8.7 PPG. -ACTUAL ROTATE TIME 2 HRS. 1*LOSS RATE TO FORMATION AT 10 BPH (DYNAMIC). *GEOLOGIST CALL 6-1/8"PRODUCTION HOLE TD AT 14,396'MD. 02:30 - 06:30 4.00 DRILL P PROD1 CIRCULATE AND CONDITION HOLE AT TD OF 14,396'MD -CIRCULATE 3 BOTTOMS UP -RECIPROCATE PIPE ONE FULL STAND (VARYING HEIGHTS)WHILE CIRCULATING AND ROTATING -260 GPM,2090 PSI,120 RPM,6K TORQUE ON UPSTROKE -200 GPM,1500 PSI,100 RPM,6K TORQUE ON DOWNSTROKE -PUMP HI-VIS SWEEP AFTER FIRST BU- OBSERVED 25%INCREASE IN CUTTINGS *LOSS RATE TO FORMATION AT 10 BPH (DYNAMIC). *SPR'S OBTAINED AT 14,396'MD. Printed 7/6/2015 11.00:17AM • North America-ALASKA-BP • Page 67 of 71 Operation Summary Report Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06.30 - 11:00 4.50 DRILL P PROD1 POOH ON ELEVATORS FROM 14,396'MD TO 9,271'MD -MONITOR WELLBORE FOR 10 MIN PRIOR TO PULL OFF BOTTOM-6 BPH LOSS RATE (STATIC) -PULL FIRST 5 STANDS WHILE WATCHING FOR SWABBING,NO SWABBING. PUT ON HOLE FILL AND TRIP TANK FOR REMAINDER OF TRIP. '-OBSERVE 5 MORE STANDS AND VERIFY CORRECT HOLE FILL. -ENCOUNTERED TIGHT SPOTS WITH 15-25K OVERPULL(13,870'MD,13,820'MD,13,710' MD,13,638'MD,13,606'MD,10,720'MD,10,285' MD).RAN IN HOLE AND PULLED BACK THROUGH EACH TIGHT SPOT WITH NO OVERPULL OBSERVED. MONITOR HOLE ON TRIP TANK -MW=8.7 PPG IN,8.7 PPG OUT 111:00 - 12:30 1.50 DRILL P PROD1 CIRCULATE AND CONDITION HOLE AT 7" SHOE(9,271'MD) CIRCULATE BOTTOMS UP 1-RECIPROCATE PIPE ONE FULL STAND -WHILE CIRCULATING AND ROTATING 260 GPM,1670 PSI I I i -70 RPM,2-3K TORQUE l-MW=8.7PPG IN,8.7PPG OUT *LOSS RATE TO FORMATION AT 3 BPH 12:30 - 14:00 1.50 (STATIC). t DRILL P � PROD1 MAKE UP RETRIEVABLE HANG OFF TOOL (MODIFIED RTTS)DRILL STRING IN WELL FOR BOP TEST -PJSM WITH RIG CREW,WSL,AND HES REP ON PLAN FOR HANGING DRILL STRING OFF ON RHOT -MU MODIFIED RTTS,CROSS OVERS, PORTED SUB,INSERT SCREEN(3-1/2"IF), CROSS OVER P/U STAND FROM DERRICK AND SET RHOT I-100'MD BELOW RKB 14.00 16:30 2.50 BOPSUR , P PROD1 PULL WEAR BUSHING,WASH STACK AND I SET TEST PLUG. -RIH W/PULLING TOOL AND ENGAGE WEAR BUSHING. L/D WEAR BUSHING. 1 -FUNCTION TEST BOPE -PU JOINT AND INSTALL BOP WASHING TOOL WASH STACK AT 8 BPM,20 RPM -WORK UP AND DOWN MULTIPLE TIMES -PU AND SET TEST PLUG AT 29.3 FT, CAMERON REP TO VERIFY AND TORQUE GLAND NUTS AND LOCK DOWNS -CAMERON REP REPLACED DAMAGED LOCK DOWN SCREW 16:30 - 19:00 2.50 BOPSUB P PROD1 RIG UP TO TEST BOPE -PU TEST JOINT,MU HEAD PIN -CONDUCT WELL CONTROL DRILL -6 BBLS TO FILL GAS BUSTER Printed 7/6/2015 11:00:17AM 111 North America-ALASKA-BP . Page 68 of 71 Operation Summary Report Common Well Name.07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) I Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 - - ----- Active datum:07-07C actual t60.72usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) I 19:00 - 23:00 4.00 BOPSUB I P PROD1 TEST BOPE TO 250 PSI LOW 3500 PSI HIGH 1 FOR 5 CHARTED MINUTES EACH. -PJSM FOR TESTING BOPE.REVIEW 1 PRESSURE CROSSCHECK AND DDI PROCEDURE FOR TESTING BOPE DISCUSS EXCLUSION ZONES,WORKING AT HEIGHTS, AND VISUAL LEAK INSPECTION. !AND VISUAL WITNESS WAIVED BY AOGCC REP LOU GRIMALDI.(AOGCC TEST NOTIFICATION WAS GIVEN ON 5/28/2015 AT 15:17) -TEST ANNULAR PREVENTER WITH 2-7/8" j TEST JOINT. 1-TEST UPPER PIPE RAMS WITH 2-7/8"AND 14-1/2"TEST JOINTS. TEST LOWER PIPE RAMS WITH 4"AND 4-1/2" TEST JOINTS -ALL TEST CHARTED,SEE ATTACHED BOP TEST CHARTS *LOSS RATE TO-FORMATION AT 3 BPH (STATIC). 23:00 - 00:00 1.00 BOPSUB P PROD1 RIG DOWN BOPE TEST EQUIPMENT. BLOW DOWN TOP DRIVE AND CHOKE LINES -PULL TEST PLUG RIG DOWN HOSES AND PLUG VALVES ON IA *LOSS RATE TO FORMATION AT 3 BPH + (STATIC). 5/31/2015 00:00 - 00:30 0.50 BOPSUB P PROD1 I INSTALL WEAR RING(9-1/4"ID) CAMERON TO RUN IN LOCK DOWN SCREWS. 00:30 - 04:30 4.00 DRILL 1 P 11 PROD1 SLIP AND CUT DRILLING LINE -PJSM ON PROPER SLIP AND CUT PROCEDURES AND ROLES -SLIP AND CUT DRILLING LINE 1 I-INSPECT SAVER SUB AS PER MANUFACTURE RECOMMENDED PRACTICE OUTLINED IN DDI PROCEDURE(GOOD CONDITION) -SERVICE TOP DRIVE AND DRAW WORKS 1-ADJUST DRAW WORKS BREAKS -CALIBRATE MWD BLOCK HEIGHT 4- - TEST CROWN-O-MATIC 04:30 - 06:00 1.50 DRILL P PROD1 RETRIEVE RHOT -PJSM ON RETRIEVING RHOT HANG OFF TOOL WITH DDI,WSLAND HES -MU STINGER TO ONE STAND OF DRILL PIPE -MU FOSV AND CLOSE TO TOP OF DRILL PIPE -RUN IN HOLE TO ENGAGE HANG OFF TOOL -TAG 1.5"HIGH,CIRCULATE TO CLEAR DEBRIS 260 GPM,40 PSI FOR 20 BBLS -ENGAGE HANG OFF TOOL WITH 21 TURNS AND PULL 10K OVER TO RELEASE -PULL RHOT TOOL OUT OF HOLE AND LAY j DOWN -LAY DOWN PORTED SUB AND DP SCREEN, OBSERVED SIGNIFICANT AMOUNT OF !DEBRIS IN BOTH THE PORTED SUB AND DP 'SCREEN TO THE POINT OF BEING PACKED OFF Printed 7/6/2015 11.00.17AM • North America-ALASKA-BP • Page 69 of 71 ,„ ,' rn Operation Summary Report , Common Well Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project.Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 11:00 5.00 DRILL P PROD1 RIH ON ELEVATORS FROM 9,271'MD TO I 14,396'MD MONITOR WELLBORE FOR 10 MIN PRIOR TO RIH-3 BPH LOSS RATE(STATIC) '-ENCOUNTERED TIGHT SPOTS WITH 10-20K I SET DOWN(10,740'MD AND 14,100'MD). PULLED UP AND RAN BACK THROUGH EACH TIGHT SPOT WITH NO SET DOWNS OBSERVED. -MONITOR HOLE ON TRIP TANK II-MW=8.7 PPG IN,8.7 PPG OUT I FILL PIPE EVERY 15 STANDS AND PUMP FOR 5 MIN AT 6 BPM FOR ARCHER TOOL -STAGE PUMPS UP AT 14,303'MD AT 1/2 BBL I INCREMENTS -168 GPM,1260 PSI,30 RPM '-WASH TOBOTTOM AND TAG AT14396'MD 11:00 - 16:00 5.00 DRILL P 1 PROD1 I CIRCULATE AND CONDITION HOLE AT TD OF 14,396'MD -CIRCULATES BOTTOMS UP '-RECIPROCATE PIPE ONE FULL STAND (VARYING HEIGHTS)WHILE CIRCULATING AND ROTATING j-260 GPM,2200 PSI,100 RPM,7K TORQUE I ON UPSTROKE j -200 GPM,1500 PSI,100 RPM,7K TORQUE ON DOWNSTROKE ! -ICP 2,260 PSI,FCP 2,200 PSI PUMP HI-VIS SWEEP AFTER FIRST BU- _ OBSERVED 0%INCREASE IN CUTTINGS -MW=8.7 PPG IN,8.7 PPG OUT *LOSS RATE TO FORMATION AT 3 BPH (STATIC). *LOSS RATE TO FORMATION AT 11 BPH (DYNAMIC). *SPR'S OBTAINED AT 14,396'MD. 16:00 - 18:30 2.50 DRILL P PROD1 I POOH ON ELEVATORS FROM 14,396'MD TO 9,405'MD -MONITOR WELLBORE FOR 10 MIN PRIOR TO PULL OFF BOTTOM-3 BPH LOSS RATE (STATIC) -PULL FIRST 5 STANDS WHILE WATCHING I FOR SWABBING,NO SWABBING. -PUT ON HOLE FILL AND TRIP TANK FOR REMAINDER OF TRIP. I -OBSERVE 5 MORE STANDS AND VERIFY CORRECT HOLE FILL. -ENCOUNTERED TIGHT SPOT WITH 15K OVERPULL(11,616'MD).RAN IN HOLE AND PULLED BACK THROUGH TIGHT SPOT WITH NO OVERPULL OBSERVED. MONITOR HOLE ON TRIP TANK-HOLE TAKING MORE THAN CALCULATED DISPLACEMENT,CONFIRMING LOSS TREND I -MW=8.7 PPG IN,8.7 PPG I 1 MONITOR WELLBORE FOR 10 MIN AFTER I PULLING BHA INTO 7"SHOE-0 BPH LOSS I RATE(STATIC) Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 70 of 71 Operation Summary Report Common Well Name.07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date 6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12.00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 20:00 1.50 DRILL P PROD1 CIRCULATE AND CONDITION HOLE AT7" SHOE(9,405 MD) -CIRCULATE BOTTOMS UP -RECIPROCATE PIPE ONE FULL STAND WHILE CIRCULATING AND ROTATING 260 GPM,1900 PSI -100 RPM,4-7K TORQUE MW=8.7 PPG IN,8.7 PPG OUT i-NO INCREASE IN CUTTINGS AT BU 20:00 - 00:00 4.00 DRILL P PROD1 ''POOH ON ELEVATORS FROM 9,405'MD TO 3,825'MD -MONITOR WELLBORE FOR 10 MIN PRIOR TO PULL OUT OF HOLE-0 BPH LOSS RATE (STATIC) i-PULL TO 7,294'MD WATCHING FOR CORRECT HOLE FILL !-MONITOR WELLBORE FOR 10 MIN PRIOR PUMPING DRY JOB-3 BPH LOSS RATE !(STATIC) PUMP DRY JOB,VERIFY SLUG CALCULATION FOR PIT GAIN I-CONTINUE PULLING OUT OF HOLE FROM 7,294'MD TO 3825'MD MONITOR HOLE ON TRIP TANK -MW=8.7 PPG IN,8.7 PPG 6/1/2015 00:00 01:00 1.00 DRILL I P PROD1 POOH ON ELEVATORS FROM 3,825'MD TO 2,638'MD -MONITOR HOLE ON TRIP TANK,HOLE TAKING SLIGHTLY MORE THAN CALCULATED I HOLE FILL,AVERAGE LOSS RATE OF 3 BPH -MW=8.7PPG IN,8.7PPG 01:00 02:00 1.00 DRILL P PROD1 'CIRCULATE AND WASH 7"LINER TOP AT 2,638'MD -CIRCULATE BOTTOMS UP -RECIPROCATE PIPE SLOWLY ACROSS !LINER TOP WHILE CIRCULATING -DID NOT SEE AN INCREASE IN RETURNS ON BOTTOMS UP 260 GPM,1290 PSI MW=8.7 PPG IN,8.7 PPG OUT 02:00 - 03:30 1.50 DRILL P PROD1 ,POOH ON ELEVATORS FROM 2,638'MD TO 274'MD -MONITOR WELLBORE FOR 10 MIN PRIOR TO PULL OUT OF HOLE-3 BPH LOSS RATE ,(STATIC) -MONITOR HOLE ON TRIP TANK -MW=8.7 PPG IN,8.7 PPG Printed 7/6/2015 11:00:17AM • North America-ALASKA-BP • Page 71 of 71 Operation Summary Report Common Wet Name:07-07A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/24/2015 End Date:6/1/2015 X3-01625-C:(7,815,980.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code 1 NPT NPT Depth Phase Description of Operations — (hr) (usft) _..l 03:30 - 05:30 2.00 DRILL P PROD1 LAY DOWN 6-1/8"PRODUCTION BHA I -PJSM WITH DDI AND SLB ON LAYING DOWN BHA AND REMOVING SOURCE FROM BHA -FOLLOWING SLB PROCEDURE FOR REMOVAL OF SOURCE MONITOR WELLBORE FOR 10 MIN PRIOR TO ;PULLING BHA THROUGH BOP-3 BPH LOSS RATE(STATIC) : -UD NON-MAG FLEX COLLARS,3 DRILL COLLARS TO PIPE SHED AND REMOVE SOURCE FROM ADN -BREAK OUT AND L/D ADN,IMPULSE MWD, ARCHER,AND 6-1/8"PDC BIT , -6-1/8"PDC BIT GRADE:2-2-BT-A-X-I-LT-TD ' 1 ' '-CLEAR AND CLEAN RIG FLOOR ' FINAL REPORT FOR 07-07C RON EVENT. Printed 7/6/2015 11:00:17AM i • North America-ALASKA-BP Page 1 of 8 Operation Summary Report Common Well Name.07-07A AFE No Event Type:COM-ONSHORE(CON) Start Date:6/1/2015 End Date:6/10/2015 X3-01625-C:(2,889,076.00) Project:Prudhoe Bay 7 Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) — T (usft) 6/1/2015 05:30 - 08:30 3.00 CASING P I RUNPRD I MOBILIZE 4.5"PRODUCTION LINER RUNNING TOOLS TO RIG FLOOR -P/U POWER TONGS,SLIPS,ELEVATORS, SAFETY JT X/O.AIR SLIPS RIG UP TOOLS FOR RUNNING LINER 08:30 - 00:00 15.50 CASING fi P I I RUNPRD I RUN 4.5"VT,12.6#,13CR,PRODUCTION I LINER TO 8,192'MD CHECK FLOATS AS PER PROCEDURE I OUTLINED IN WELL PROGRAM,WSL VERIFY FLOATS HOLDING -BAKER-LOK SHOE TRACK I- USE JET LUBE SEAL GAURD FOR VAM-TOP [THREADS '-TORQUE CONNECTIONS TO 4,400 FT-LBS [-RUN 2 FLOATING CENTRALIZERS ON JOINTS 1-120 AND 123 • -FILL CASING EVERY JOINT,TOPPING OFF I EVERY 10 JOINTS 1-PU 60K,SO 60K MAKE UP LINER HANGER/PACKER ASSEMBLY AT 5,062'MD '-ADD PAL MIX BREAK CIRCULATE , 1-PU 112K,SO 105K CONTINUE IN HOLE FROM 5,062'MD TO 8,192' 1 ' , MD ON 4"DRILL PIPE -FILL PIPE EVERY 10 STANDS AND BREAK 1 I CIRCULATION -RIH AT 60-100 FT/MIN '-MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT MUD LOSSES WHILE RIH:3 BPH I -PU 152K,SO 132K 'KICK WHILE TRIPPING DRILL,ERT 2:00 MIN, AAR PERFORMED 6/2/2015 [00:00 - 07:30 7.50 CASING P RUNPRD RUN 4.5",12.6#,13CR,PRODUCTION LINER 1 [FROM 8,192'MD CONTINUE IN HOLE TO 9,400'MD(7"SHOE) 'ON 4"DRILL PIPE RIH AT 60-80 FT/MIN -CIRCULATE 1.5X BOTTOMS SLOWLY STAGING UP TO 7 BPM,900 PSI -PU 175K,SO 155K RUN INTO OPEN HOLE WITH LINER -BREAK CIRCULATION EVERY 10 STANDS AT '3.0 BPM FOR 5 MINUTES OBTAIN PU/SO WEIGHTS EVERY 10 STANDS -RIH AT 60-80 FT/MIN -MUD WEIGHT:8.7 PPG IN,8.7 PPG OUT MUD LOSSES WHILE RIH:3 BPH -PU 215K,SO 150K -PICK UP 4"DP SINGLE FROM SHED AND M/U CEMENT HEAD AND LINES -STAGE UP TO 1 BPM,780 PSI AND WASH TO BOTTOM -TAG BOTTOM AT 14,396'MD -TOP OF LINER AT 9,294'MD -NO ISSUES RUNNING IN OPEN HOLE. Printed 7/6/2015 11:00:54AM • North America-ALASKA-BP • Page 2 of 8 Operation Summary Report Common Well Name:07-07A AFE No Event Type:COM-ONSHORE(CON) Start Date:6/1/2015 End Date'6/10/2015 X3-01625-C:(2,889,076.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code N PT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 14:30 7.00 CEMT P RUNPRD CIRCULATE AND CONDITION MUD FOR CEMENT JOB I ,STAGE UP TO CEMENTING RATE IN 0.5 BPM INCREMENTS TO FINAL CIRCULATING RATE OF 6 BPM. -@ 1.5 BPM,870 PSI,8%RETURN FLOW -@ 2.5 BPM,970 PSI,14%RETURN FLOW -@ 4.0 BPM,910 PSI,11%RETURN FLOW -@ 5.5 BPM,1520 PSI,22%RETURN FLOW -@ 6.0 BPM,1650 PSI,24%RETURN FLOW I CONDITION MUD TO 8.75 PPG I-INITIAL PRESSURE AT CEMENTING RATE: 1700 PSI -FINAL PRESSURE AT CEMENTING RATE AFTER HOLE CONDITIONED:1650 PSI , I-CIRCULATE TOTAL OF 3 TIMES BOTTOMS UP '-RECIPROCATED PIPE 20 FT AT SURFACE -MUD LOSSES:21 BBL -CONDUCT PJSM WITH DDI,WSL,AND SLB. , DISCUSSED PRESSURE CROSSCHECK FOR PRESSURE TESTING LINES AND CEMENTING I 1PROCEDURES. ' .-VERIFY TRIPS IN CEMENT TRUCK Printed 7/6/2015 11:00'54AM •North America-ALASKA-BP Page 3 of 8 Operation Summary Report Common Well Name.07-07A AFE No Event Type:COM-ONSHORE(CON) Start Date:6/1/2015 End Date:6/10/2015 X3-01625-C:(2.889,076.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) ' (usft) 14:30 - 18:00 3.50 CEMT P !, RUNPRD CEMENT 4.5"PRODUCTION LINER AS FOLLOWS: -FILL LINES WITH WATER AND PRESSURE TEST TO 4,700 PSI FOR 10 MINUTES PUMP 50 BBLS OF 10 PPG MUDPUSH II SPACER @ 5 BPM,1100 PSI If I -PUMP 125 BBLS OF 15.8 PPG CLASS G TAIL @ 5 BPM,EXCESS VOLUME 40% (YIELD 1.16 CU.FT/SK) I-DROP DRILL PIPE WIPER DART,OBSERVE TATTLE TAIL -RECIPROCATED PIPE 20 FT AT SURFACE WHILE PUMPING CEMENT AT 5 BPM PERFORM DISPLACEMENT WITH SLB CEMENT TRUCKS -DISPLACED AT 2-6 BPM:ICP 870 PSI 10% RETURN FLOW,FCP 2300 PSI 25%RETURN FLOW -DISPLACEMENT FLUID:8.7 PPG, POWERPRO. -LATCH UP NOT OBSERVED REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP:FINAL CIRCULATING PRESSURE 2300 PSI BUMP THE PLUG WITH A FINAL DISPLACEMENT VOLUME 170.7 BBLS,3 BBLS PRIOR TO CALCULATED VOLUME. -RECIPROCATE PIPE 20 FT AT SURFACE DURING DISPLACEMENT,STOP RECIPROCATION WHEN CEMENT EXITS SHOE. -TOTAL LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE:0 BBLS -INCREASE PRESSURE TO 3500 PSI TO SET HANGER AFTER PLUG BUMP AS DIRECTED BY BOT -SET DOWN 50K TO CONFIRM HANGER SET CHECK FLOATS-GOOD -PU TO EXPOSE DOG SUB AND SET DOWN 40K ON LINER TOP TO SET ZXP -BROKE CEMENT LINE AND CAP,PICK UP AND ROTATE 15 RPM,4K TORQUE,SLACK OFF 45K 2X,CONFIRM SET PRESSURE UP TO 850 PSI -PU TO REMOVE RS PACK-OFF,OBSERVE PRESSURE DROP AND CIRCULATE EXCESS CEMENT OFF LINER TOP -PU RUNNING TOOL ABOVE LINER TOP AND MARK NO-GO.CIRCULATE 1X BU AT 6 BPM -CIRCULATE OUT 140 BBLS OF CONTAMINATED MUD PUSH AND CEMENT --38 BBLS OF EXCESS CEMENT TO SURFACE ON BOTTOMS UP -CEMENT IN PLACE AT 16:05 Printed 7/6/2015 11:00:54AM • North America-ALASKA-BP • Page 4 of 8 Operation Summary Report Common Wet Name:07-07A AFE No Event Type:COM-ONSHORE(CON) Start Date:6/1/2015 End Date:6/10/2015 X3-01625-C (2,889,076.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date I From-To I Hrs Task Code NPT NPT Depth I Phase Description of Operations 18:00 - 00:00 6.00 CEMT P (usft) I RUNPRD CLEAN AND CLEAR RIG FLOOR -RIG DOWN CEMENTING EQUIPMENT -BREAK OUT CEMENT HEAD,2 SINGLES AND 5'PUP AND LAY DOWN -MAKE UP TO TOP DRIVE,DRAIN STACK AND I SOAK WITH BLACK WATER PILL. • CLEAN PITS TO PREP FOR TAKING ON II BRINE FOR DISPLACEMENT PERFORM DROPS INSPECTION ON TOP I DRIVE AND DERRICK INSPECT DRAWWORKS,IRON ROUGHNECK 6/3/2015 00:00 - 03:00 3.00 CASING P RUNPRD I DISPLACE WELLABOVE LINER TOP FROM 8.7 i PPG FLOWPRO TO 8.5 PPG BRINE AT 9,290' I IMD I-TAKE ON BRINE TO PITS AND PREP FOR I DISPLACEMENT -LEAD WITH BRINE HI-VIS SPACER I-320 GPM,1120 PSI ICP,910 PSI FCP ' -NO ROTATION OR RECIPROCATION DISPLACE 510 BBLS -OBTAIN SPR AT 9,290'MD 03:00 - 11:30 8.50 CASING P RUNPRD ,POOH WITH LINER RUNNING ASSEMBLY FROM 9,290'MD TO LINER RUNNING TOOL. MONITOR WELL FOR 10 MINUTES PRIOR TO I PULLING OFF BOTTOM,STATIC -LAY DOWN 4"DP SINGLES TO PIPE SHED I-MONITOR WELL ON TRIP TANK MW=8.5 PPG IN,8.5 PPG OUT -HOLE FILL DISPLACEMENT DISCREPANCY AT 2,200'MD,STOP AND FLOW CHECK FOR 10 MINUTES AT 2,200'MD,WELL STATIC `UNANNOUNCED KICK WHILE TRIPPING DRILL(ERT 3:20) 11:30 - 13:30 2.00CASING P RUNPRD I RIH ON 4"DP STANDS OUT OF THE DERRICK TO 2,620'MD -MONITOR WELL ON TRIP TANK -MW=8.5 PPG IN,8.5 PPG OUT 3:30 16:00 2.50 CASING P RUNPRD POOH :1 - WITH LINER RUNNING ASSEMBLY 1 • FROM 2,620'MD AND LAY DOWN LINER RUNNING TOOL. -MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM,STATIC -LAY DOWN 4"DP SINGLES TO PIPE SHED -MONITOR WELL ON TRIP TANK -MW=8.5 PPG IN,8.5 PPG OUT 16:00 - 17:30 1.50 CASING P RUNPRD RIH ON 4"DP STANDS OUT OF THE DERRICK • TO 2,278'MD MONITOR WELL ON TRIP TANK -MW=8.5 PPG IN,8.5 PPG OUT 17:30 - 20:00 2.50 : CASING P : RUNPRD POOH WITH 4"DP FROM 2,278'MD TO :SURFACE. -MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM,STATIC -LAY DOWN 4"DP SINGLES TO PIPE SHED -MONITOR WELL ON TRIP TANK -MW=8.5 PPG IN,8.5 PPG OUT Printed 7/6/2015 11:00:54AM • North America-ALASKA-BP 0 Page 5 of 8 Operation Summary Report Common Well Name 07-07A AFE No Event Type.COM-ONSHORE(CON) Start Date:6/1/2015 End Date:6/10/2015 X3-01625-C:(2,889,076.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. .UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20.00 - 21:00 i 1.00 CASING P RUNPRD PRESSURE TEST 4.5"PRODUCTION LINER TO 250 PSI LOW FOR 5 MIN/3,500 PSI HIGH FOR I 30 MIN -PASSING TEST ON 4.5"PRODUCTION LINER -TEST APPROVED BY BP TL,JIM I i WWILLINGHAM -BLOW DOWN CHOKE AND KILL i-RIG DOWN TEST EQUIPMENT 21 00 - 00 00 3.00 RUNCOM P 1 RUNCMP PREP FOR RUNNING 4.5"COMPLETION I PULL WEAR RING RIG UP SAFETY JOINT,LANDING JOINT, !COMPLETION TOOLS,TONGS AND ELEVATORS 6/4/2015 00:00 - 16.30 16.50 RUNCOM P RUNCMP RUN 4.5",12.6#,13CR,VAM-TOP COMPLETION TUBING FROM SURFACE TO 9,306'MD AND TAG USE JET LUBE SEAL GUARD ON , CONNECTIONS BAKER-LOK ALL CONNECTIONS BELOW PACKER -TORQUE CONNECTIONS TO 4,400 PSI ' !-RUN IN HOLE AT 80 FT/MIN -MONITOR HOLE ON TRIP TANK BRINE WEIGHT:8.5 PPG IN,8.5 PPG OUT !16:30 - 17:30 1.00 RUNCOM P RUNCMP SPACE OUT 4.5",12.6#,13CR,VAM-TOP COMPLETION TUBING HALF WAY INTO 4.5" LINER TOP PBR,4.34'OFF NO-GO/WLEG AT 19,301'MD MAKE UP SPACE OUT PUPS E(7.73')AND F (9.83') -MAKE UP JOINT#214 1 -MAKE UP TUBING HANGER WITH LANDING i JOINT 1-VERIFY PIPE COUNT IN PIPE SHED -CAMERON AND WSL VERIFY TUBING HANGER LANDED 1 -RILDS AND TORQUE PER CAMERON 1 PROCEDURE DRAIN STACK AND RIH WITH HANGER -P/U=160K,5/0=135K I LAND TUBING HANGER AT 17:30 17:30 - 20:30 3.00 RUNCOM P RUNCMP RIG UP TO REVERSE CIRCULATE SEAWATER AND CORROSION INHIBITOR -RIG UP ALL LINES AND MANIFOLD PER DDI SOP -PRESSURE TEST SURFACE EQUIPMENT TO 250 PSI/LOW,3500 PSI/HIGH 20:30 - 00:00 3.50 RUNCOM P RUNCMP REVERSE CIRCULATE 120 DEGREE SEAWATER AND CORROSION INHIBITOR CIRCULATE DOWN IA AND TAKE RETURNS I UP THROUGH TUBING -3 BPM,350 PSI(MAX ALLOWABLE,600 PSI) -144 BBLS SEAWATER -115 BBLS CORROSION INHIBITED SEAWATER -159 BBLS SEAWATER -5 BBLS EXTRA SEAWATER -CIRCULATE 5 BELS DOWN TUBING AND TAKE RETURNS UP THROUGH IA TO CLEAN OFF RHC -2 BPM,100 PSI(MAX ALLOWABLE,600 PSI) Printed 7/6/2015 11:00:54AM 0 North America-ALASKA-BP • Page 6 of 8 Operation Summary Report Common Well Name:07-07A AFE No Event Type:COM-ONSHORE(CON) Start Date:6/1/2015 End Date:6/10/2015 X3-01625-C:(2,889,076.00) Project:Prudhoe Bay Site:PB DS 07 • Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs • Task Code NPT NPT Depth Phase Description of Operations • (hr) (usft) 6/5/2015 00:00 01:00 1.00 RUNCOM P RUNCMP RIG UP FOR SETTING COMPLETION PACKER AND PRESSURE TESTING TUBING AND IA -HOLD PJSM FOR PRESSURE TESTING I -RIG UP PER DDI SOP ! -DROP BALL AND ROD 101:00 - 04:00 3.00 RUNCOM P • RUNCMP !SET COMPLETION PACKER AND PRESSURE TEST 4.5"COMPLETION TUBING TO 250 PSI LOW FOR 5 MIN/3,500 PSI HIGH FOR 30 MIN :EACH -POSITIVE INDICATION OF PACKER SET AT 2,100 PSI WHILE PRESSURING UP TO 3,500 PSI FOR 30 MIN TEST 1-PASSING TEST ON 4.5"COMPLETION TUBING : BLEED PRESSURE ON TUBING DOWN TO 2,000 PSI AND HOLD • PRESSURE TEST 4.5"COMPLETION TUBING X i 9-5/8"/7")IA TO 250 PSI LOW FOR 5 MIN/ 3,500 PSI HIGH FOR 30 MIN EACH -PASSING TEST ON 4.5"COMPLETION ' • TUBING X(9-5/8"/7")IA 1-TEST APPROVED BY BP vol,JIM I WILLINGHAM BLEED PRESSURE OFF OF TUBING TO SHEAR DCK VALVE IN UPPER GLM -POSITIVE INDICATION OF DCK VALVE SHEAR AT 900 PSI ON TUBING : I -6 BBLS PUMPED TO PRESSURE UP AND 6 BBLS BLED BACK PUMP 8 BBLS BOTH WAYS TO CONFIRM GOOD SHEAR -129 GPM,1950 PSI PUMPING DOWN THE IA 129 GPM,1000 PSI PUMPING DOWN THE : TUBING I -RIG DOWN TEST EQUIPMENT 04:00 - 09:00 5.00 RUNCOM P RUNCMP RIG UP WITH LRS AND FREEZE PROTECTING WELL. FREEZE PROTECT TUBING X IA -REVERSE CIRCULATE 140 BBLS OF DIESEL -1.5 BPM,ICP 300 PSI,FCP 415 PSI .-90 DEGREE DIESEL -U-TUBE DIESEL TO EQUALIZE TUBING AND IA FOR 1 HOUR -FREEZE PROTECT DEPTH TO 2,000'MD 09:00 - 12:00 3.00 WHSUR P RUNCMP INSTALL TWC AND PRESSURE TEST FROM ABOVE AND BELOW ' -CONDUCT PJSM WITH DDI AND WSL ' -VERIFY 1 HOUR MONITOR AND STATIC PRIOR TO INSTALLATION DRY ROD TWC INTO PLACE -PRESSURE TEST TWC FROM ABOVE TO 250 PSI LOW FOR 5 MIN/3500 PSI HIGH FOR 30 MIN EACH -PRESSURE TEST TWC FROM BELOW TO 250 PSI LOW FOR 5 MIN/3500 PSI HIGH FOR 30 MIN EACH -GOOD TESTS Printed 7/6/2015 11:00:54AM North America-ALASKA-BP S Page 7 of 8 Operation Summary Report Common Well Name:07-07A AFE No Event Type:COM-ONSHORE(CON) Start Date:6/1/2015 End Date:6/10/2015 X3-01625-C:(2,889,076.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 I Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual©60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 BOPSUR P I RUNCMP R/D EQUIPMENT,INSPECT AND CHANGE OUT BOPE PJSM PERFORMED PRIOR TO EACH SEPARATE JOB WITH AN SOP -SUCK OUT BOPE,CHOKE SKID,AND HIGH PRESSURE LINES TO RIG FLOOR. -BLOW DOWN CHOKE/KILL LINES. L/D MOUSE HOLE. CHANGE BOP TOP RAMS TO 9-5/8"CASING RAMS CHANGE OUT SEALS ON 9-5/8"CASING RAMS -BLEED OFF PRESSURE HYDRAULIC PRESSURE FROM ACCUMULATOR -CHANGE OUT TOP SEALS ON BLIND/SHEAR RAMS -LOWER 3-1/2"X 6"SEALS GOOD(TAP ONE BOLT HOLE) -NIPPLE DOWN FLOWLINE/RISER 'SIMOPS - 1-CLEANING PITS AND INSPECTING EQUIPMENT I,-INSPECT SAVER SUB ON TOP DRIVE-GOOD CONTINUE RIGGING DOWN ROCKWASHER FOR MOVE -WORK ON MUD PUMPS SUCTION TUBES AND INSTALL LINER BOOM ASSY -HELP CAT TECHNICIAN ON CAT#2 -CONTINUE STAGING EQUIPMENT ON THE PAD FOR RIG MOVE *24 HR NOTICE GIVEN TO AOGCC ON BOP TEST AT 18:32 ON 6/5/2015 6/6/2015 00.00 - 03:00 3.00 BOPSUR P RUNCMP CONTINUE TO NIPPLE DOWN BOPE -CONTINUE INSTALLING BLIND/SHEAR RAMS DOUBLE CHECK TORQUE ON LOWER RAM DOORS INSPECT ANNULAR USING THE BORE SCOPE TOOL- GOOD CONDITION DDI TOOL PUSHER VERIFIED -CLEAN REMAINING MUD PITS -READY ROCK WASHER TO BE MOVED. 03:00 - 05:00 2.00 BOPSUR P RUNCMP NIPPLE DOWN BOP STACK -PERFORM PJSM WITH DDI AND WSL -NIPPLE DOWN BOP STACK -REMOVE KILL LINES -RACKBOPSTACKBACKONSTUMP Printed 7/6/2015 11:00:54AM • North America-ALASKA-BP Page 8 of 8 Operation Summary Report Common Well Name:07-07A AFE No Event Type:COM-ONSHORE(CON) Start Date:6/1/2015 End Date:6/10/2015 X3-01625-C:(2,889,076.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:DOYON 14 Spud Date/Time:11/24/1978 12:00:00AM Rig Release:6/6/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292090100 Active datum:07-07C actual @60.72usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 11:00 6.00 WHSUR P ' RUNCMP NIPPLE UP ADAPTOR FLANGE AND DRY HOLE TREE. -PERFORM PJSM WITH DDI,WSL,AND ICAMERON I-MAKE UP ADAPTOR FLANGE -PRESSURE TEST ADAPTOR FLANGE VOID TO 250 PSI LOW/5000 PSI HIGH FOR 5 MIN EACH -MAKE UP TREE AND OTIS CAP PRESSURE TEST TREE WITH DIESEL TO 250 !PSI LOW/5000 PSI HIGH FOR 5 MIN EACH -SUCK OUT DIESEL AND FILL TREE WITH 4 BOTTLES OF HEET ON TOP OF TWC I*RIG RELEASE FROM 07-07C AT 11:00 ON 6/6/2015 AND BEGIN MOVE TO 07-34B. Printed 7/6/2015 11:00:54AM • • 07-07C, Well History (Post-Rig Sidetrack) T/I/O= 0/0/0 Removed 4" CIW Temp SV(dry hole tree): Installed upper tree, Torqued to API specification; Pt Tree to 300 psi-low&5000 psi-high (passed); Pulled 4"CIW TWC#425; Removed 2nd (piggy back) IA& OA& installed blind flanges, torqued to API specification & PT to 2500 psi 6/7/2015 (passed); FWP= 0/0/0. PULLED BALL AND ROD FROM RHC PLUG BODY @ 9,262' SLM. PULLED BK-DGLV FROM STA#3 @ 5,805' SLM/5,820' MD. PULLED BEK-DCK FROM STA#4 @ 3,607' SLM/3,624' MD. SET BK-LGLV IN STA#4 @ 3,607' SLM /3,624' MD. SET BK-OGLV IN STA#3 @ 5,805' SLM/ 6/9/2015 5,820' MD. PULLED 4-1/2" RHC PLUG BODY FROM XN NIPPLE @ 9266' SLM/9284' MD. Coil 8, 1.5"coil, CTV=23.2 Job Scope: Drift, RPM log and Initial perf. MIRU Coil 8. Double barrier test. M/U CTC, pull test. M/U MHA, fill coil and press test. M/U stingers and 3.0"drift nozzle. One pick BOPE. PT lube. RIH, circ min rate with Safelube for chrome tubing. RIH at 80 fpm. Safety Meeting. Drift to PBTD @ 14322 dn/ 14304 up. Had problems getting to bottom due to coil lockup 6/19/2015 but eventually made it. Circulate well to 1% KCI with safelube from PBTD. POOH. Coil 8, 1.5"coil, CTV= 23.2 Job Scope: Drift, RPM log and Initial perf. Continue POOH with 3.0" Drift nozzle. MU Baker RPM. RIH to 10150'. Log down to PBTD @ 30 fpm. Tag @ 14,315'wgt back @ 14,302' - Log Up 20 fpm - Paint a FLAG @ 14,000' E 13,972' M -YELLOW-Continue Log Up 20 fpm to 10,150' -Jewelry Log Up 30 fpm to 8550' - RIH pumping Diesel w/776 lube to displace KCL- @ 9412' stop RIH -small Pinhole in CT- PUH to 300' -wait for RPM Tools to turn off. POOH. 6/20/2015 RDMO. Road to yard for pipe swap. CTU#8 w/1.5" CT. CTV= 25.2. Job Objective: MGR/CCL Coil Flag and Perforate 20'. Road Unit to 6/21/2015 loaction after pipe swap. MIRU. RIH w/PDS MGR/CCL in 2.20"carrier and 3.0" nozzle drift. CTU #8 w/1.5" CT. CTV= 25.2 Job Objective: MGR/CCL Coil Flag and Perforate 20'. RIH w/ PDS MGR/CCL in 2.20"carrier and 3.0" nozzle drift. Tag PBTD @ 14317 dn / 14303 up. Log from 14303' - 13500'. Stop @ 14000' and paint flag. Circulate well to diesel from 10,900'to surface. 6/22/2015 Check log data. PDS tool stopped working while RIH. Need to rerun log. CTU#8 w/1.5" CT. CTV=25.2. Job Objective: MGR/CCL Coil Flag and Perforate 20'. RIH w/ PDS MGR/CCL in 2.20"carrier and 3.0" nozzle drift. Tag PBTD @ 14317 dn/ 14303 up. Log from 14303' - 13500'. Stop @ 14000' and paint flag. Circulate well to diesel from 10,900'to surface. Check log data. PDS tool stopped working while RIH. Need to rerun log. PJSM. M/U PDS memory logging. BHA. PT lube. RIH 80 fpm. Stacking wt below 13200'due to diesel in tubing. Stop at 14120'. Log up to flag at 14020'. Park 5 min. Log up to 9000'. POH. PJSM. Lay out PDS. Good data. correction = -5.5' to put PDS on depth. PJSM. M/U SWS 20' perf BHA. PT lube. RIH with 20' perf 6/22/2015 BHA. Perforate interval 14050' - 14070'with 20' of 2-7/8" HSD 2906 PJ, HMX. SI well, POOH. CTU #8 w/1.5" CT. CTV=25.2. Job Objective: MGR/CCL Coil Flag and Perforate 20'. POOH with 6/23/2015 20' perf gun. Unstab. ASF. RDMO. 411 III 0 0„....... 0,,,-....M m'-Nn O a W mrm W JH N 9 W-m NvN,M o,0am0 mamN W M W O W M mrH c8 m m2m,0 66666 6666 6606066 66666 cd 666 m Q a a a a a a a a a a 44.4-44 aaaaa a a v v a a,a a a a,. O O m Oa a CO 4E82,222 ^Omaa N0rMm N,•m00, OWW M OF mM - J 22222 2 mmmMMMMM WMOO P.'22-- ,N N N a a 22222 NNMm Oq mmmmm mmmmmmmmmm mmmmm WWWWW WWWWW WW O Aro,,nmrrnn mmmm, rr, , rnn,n m,,,n r, NJ mmmmm ...coo wow.. ow... mmmmm mmmm w. 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K.BENDER Customer: BP Exploration Alaska Inc Dispatched To: Makana Bender Well No: 07-07C Date Dispatched: 6-Jul-15 APIN: 50-029-20901-02-00 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Delivered To: O6JUL15-SP01 AOGCC Makana Bender 8 total Contents on CD N/A Color Log Prints: 5 VISION*Services 2"MD x x VISION*Services Y TVD i' tUti CID x x VISION*Services 5"MD x x VISION*Services 5'TVD JUL 06 ?ti1;.1 x x VISION*Services 5"MD Quadrant Density x x AOGCC Digital Data N/A Contents on CD x Survey 2 Contents on CD ASP Final Survey x x EOW CD 1 Contents on CD Graphics:PDF x Data:DLIS/ASCII x Survey:PDF,XLS x Please sign and email a copy to: Please sign and email a copy to: AlaskaPTSPrintCenter(aslb.com gancpdcLbp cor Alaska PTS Print Center ATTN: Merion Kendall Received By: o_zotteet III • p y O <L)O r r O-1 N N D W N m f1 e 4 O ry W O N' .71 A 0 O a z Cz z Cz 9 O ' n N A m al N A J g e O O �D O C p.3 0 w a u -paJJmo.E m - p _�•. 1(:X1 w'y?C L1 m_ON m N N N S c g o A O .. 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(mandatory) COUNTY North Slope Borough C E LOP RPM -Wireline (mandatory) (mandatory) STATE Alaska *JUL •6121s(IjRICT Alaska (mandatory) (mandatory) LOG DATE: May 20,2015 AOGCC TODAYS DATE:gee a vE (mandatory) ��ll �s DISTRIBUTION LIST AUTHORIZED BY CANIZARES EMAIL: je (mandatory) JUL 0 6 2tJ1tt J HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No AOGO ? COMPANY I ADDRESS A B C D L.I.S. FILM PERSON ATTENTION #OF PRINT:#OF COPIE#OF COPIE#OF COPIES#OF COPIE #OF COPIES 1 ConocoPhillips Alaska Inc. 1 I 1 1 I 1 Attn:Ricky Elgaricio A= 07-07C_MRPM_RAW_20JUN2015_BHI_V2.meta ATO 3-344 B= *(Folder 1 on cd/dvd) 07-07CMRPM_RAW_20JUN2015_BHI_V2.meta 700 G Street C= **(Folder 2 on cd/dvd) 07-07C_MRPM_RAW_20JUN2015_BHI_V2.PDF Anchorage,AK 99510 D= ***(Folder 3 on cd/dvd) 07-07C_MRPM_RAW_PASSO1 DOWN_20JUN2015_BHI_2.dlis 07-07C MRPM RAW PASSO2UP 20JUN2015BHI 2.dlis ****(Folder 4 on cd/dvd) 07-07C_MRPM_RAW_PASSO1 DOWN_2OJUN2015_BHI_2.1as 07-07C MRPM RAW PASSO2UP_20JUN2015_BHI_2.las * Folder 1 on cd/dvd needs to be named "META" ** Folder 2 on cd/dvd needs to be named "PDF" *** Folder 3 on cd/dvd needs to be named "DLIS" **** Folder 4 on cd/dvd needs to be named "LAS" 2 ExxonMobil,Alaska 1 1 I 1 1 I I Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 3 State of Alaska-AOGCC 1 I 1 I 1 I 1 I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 4 DNR-Division of Oil&Gas 0 I 0 I 1 1 I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 3 4 4 4 0 0 TOTALS FOR ALL PAGES: 3 4 4 4 0 0 • • pro 219 —)7s Loepp, Victoria T (DOA) From: Loepp, Victoria T(DOA) Sent: Friday,April 10, 2015 9:53 AM To: 'Gorham, Bradley M' Cc: Davies, Stephen F (DOA) Subject: 07-07C (PTD 214-175) Change of Scope -Int Cement Brad, Your plan to perform a 1500' single stage cement job to bring TOC to^'7,900' MD instead of the originally planned two stage cement job is approved. Please update the PTD with this change approval.A revised PTD is not necessary. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 V ictoria.Loepp(a.alaska.qov CONFIDENTIALITY NOTICE:1 his e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Gorham, Bradley M [mailto:Bradley.Gorham@abp.con:] Sent: Wednesday, April 08, 2015 9:18 AM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N; Allen, Kenneth W Subject: 07-07C Change of Scope Victoria, I wanted to inform you of a change of scope to the upcoming well 07-07C.As you'll remember,we have already adjusted the intermediate completion from a 7" long string to a 7" liner. When that change was made,the planned top of cement(3,350' MD TOC) on the intermediate cement was not adjusted.The total height of the planned intermediate cement job was 6,132' MD. In order to bring the TOC that high, a two-stage job was going to be utilized. However, after further evaluation, it has been deemed unnecessary to bring our TOC that high.This is due to the fact there will now be a 7" liner top packer that will provide adequate isolation.The new plan is to perform our standard 1,500' single stage cement job that would bring the TOC to 7,900' MD. I have attached two schematics showing the new and old proposed plans for your review. Please review the information and advise us if we need to submit a new Permit to Drill prior to moving over this well. Doyon 14 is scheduled to move to 07-07C around the 22' of April. We apologize for the late notice and if necessary will get you a revised PTD as soon as possible. Thanks, TRS= GRAY GEN 3 V11aLHFAD= GRAY PROPO 07-07C SA.NOTES: ACTUATOR= AXE-SON KB.BBV= 70' BF.B-BI= ? __ _ ? I I III KOP= 2800' e#, -9 XN NIP ID=3.813" Max Angle= 49 @ 9800' ID= " j IIIII 2352' 1-- Full Open Collar Dahm M3= 10633' WD= 8800's42300'H 9-5/8" Cut& Pull IT2478' 1-- Full Open Collar 113-3/8"CSG,72#, L-80 ID= 12.347"H 2496' I-- AI Si 9-5/8"WHIPSTOCK(_/_/___) -2750' -2600' _JTOP OF 7"LNR 9-5/8"CSG,47#, L-80, ID=8.681" —I 2759 h 9-5/8"EZSV, (_/_/_) H 1 MILLOUT WINDOW(07-07C)-2739--2740 GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE TOP OF CEMENT(3260') -3350' 4 _ . ► 3 4 2 t, ► 1 BAKER PAC VALVE 6,900' K w ' w 4-1/2"HES XN NIP, ID=3.813" BArL.,. -6,950' 17.' ._ b -9200 7"X 4-1/2"HES TNT PKR, ID=3.870" toi w _ 4-1/2"HES XN NIP, ID=3.813" 11 a _ 4-1/2"HES XN NIP, ID=3.813" I 4-1/2"TBG, 12.6#, 13CR-85 VAM TOP, .0152 bpf, ID=3.958" -9327 4,. '+ j i -9;, 7"X 5"BKR TIEBACK SLV, ID= " /TOP OF 4-1/2"LNR CEMENTED -9332' : -9327 4-1/2"WLEG, ID=3.958"tie, - .�w I VI! 0;'k -9332 7"X 5"BKR ZXPN LTP,ID= PO k 14iH5"X4-112"XO,ID=__ 'LNR,26#,L-80 VAM TOP HC, .0383 BPF, ID=6.276"H-9482' y i ,.k - RA TAG F IF i I. F1 r4. FERFORATION SUMMARY r 1.0 REF LOG: ON / 1 ANGLEATTOP PERF: " ►wi 0IINate:Refer to Production DB for historical perf data rfi SIZE SPF INTERVAL Opn/Sqz SHOT SOZ i RA TAG II VI* lel.14 l 'Oil V ii.moov.voII. PBTD 4114, 4 I-14 ,240'— 4-1/2"LNR, 12.6#, 13CR-85 VAM TOP, .0152 bpf, ID=3.958" GATE REIT BY COP/MNIS DAD REV BY G'OM ENTS PRIJDHOE BAY UNIT 01/04179 OIG COM PLEFION 10/13/08 JItL*JC SET PATCHS(09129/08) WILL: 07-078 03131/83 LAST WORKOVB2 03/18/10 OP ISV SET PX PLUG(03110/10) PERMT No: 2060810 06130/06 NORDIC 1 CTD('B") 10/02212 TUJIC PATCH DOTH CORRECTIONS API No: 50-029-20901-02 07/04/06 KSB/PAG GLV GO 04/2E/13 MSS/JM)RUN F?(PLUG(04/19113) SEC 33,T1114,R14E 1333'FNL&142'FE. 03/03/07 ORF/PJC DPLG DRAFT CORRECTION 3 02/07/14 PJC ADD CON]UCTOR INFO 04/30/08 CJNISV GLV CIO(04/201081 BP Exploration(Alaska) 'TREE= GRAY GEN3 V1IBLHEAD= GRAY PROPOA 07-07C S NOTES: ACTUATOR= AXELSON KB.ELL/= 70 ' (! I I LIB/BF. ? CONDUCTOR. 4-1/2"HES XN NIP, I[ 3.813" KOP= 28W _#, Max Angle= 49 @ 98W D= / IV 2352' I— Full Open Collar Datum MD= 10633' DatunTVD= 8800's:�?300' — 9-5/8" Cut& Pull 1:--- 2478' I— Full Open Collar 13-3/8"CSG,72#, L-80 ID= 12.347" 2496' kLM... 9-5/8"WHIPSTOCK L/_/� 2750' ' -2600' H'OP OF 7"LNR 9-5/8"CSG,47#, L-80, ID=8.681" —I 2759' 9-5/8"EZSV, L/_/___) —I 775 MILLOUT WINDOW(07-0701 2739--274<' GAS LFT MANDFii_._U ST MD ND DEV TYPE VLV LATCH PORT DATE IE 4 3 2 1 ' 1----H4-1/2"HES XNNIP, ID=3.813" 7" Liner TOC -7900' CI 4 R:.,01 -9200' 7"X 4-1/2"HES TNT PKR, ID=3.870" •• I 4 " e 4-1/2"HES XN NIP, ID=3.813" 41,141 I 4-1/2"HES XN NIP, ID=3.813" TBG, 12.6#, 13CR-85 VAM TOP, .0152 bpf,ID=3.958" 9327' `' 9322' 7"X 5"BKR TIEBACK SLV, 4 (TOP OF 4-1/2"LNR CEMENTED -9332' -9327 4-1/2"WLEG, ID=3.958" I , . 4 big ler =.41 -9332 7"X 5"BKR ZXPN LTP, ID= " i s. I --I5"X4-1/2"XO,10= " 17"LNR,26#,L-80 VAM TOP HC, .0383 BPF,ID=6.276" _9482' '; 4, b RA TAG f iv R3FORATION SUMMARY t# F Al � REF LOG: ON / / I `,R ANGLE AT TOP PERF: "@ ? N Note:Refer to Roduction DB for historical perf data ttf INTERVAL . A TAG SIZE SPF INTERVAL Opn/Sgz SHOT SL1Z - _ I . roi. :s • ko 0..4..... PBTD 0414.4`_ �.�4�.�� ! -14,240' 4-1/2"LNR, 12.6#, 13CR-85 VAM TOP, .0152 bpf, ID=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 01104/79 ORIGCOM PLEf1ON 10/13108 J'QPPJC SET PATCH'S(09129/08) VVEL.L: 07-07B 03/31/83 LAST WORKOVE 03/18/10 OPC/SV SET PX PLUG(03/10/10) PERMIT No: 2060810 06/30106 NORDIC 1 CTD(B") 10/02/12 11/J MU PATCH DEPTH CONS NI No: 50-029-20901-02 07/04/06 KS5/PAG GLV C/O 04/25/13 M55&JMD RUN PX PLUG(04/19113) SEC 33,T11 R14E, 1333'FNL&142 FB 03/03/07 DRF/PJC DRLG DRAFT CORRECTIONS 02/07/14 PJC ADD CONDUCTOR INFO 04/30/08 CJN/SV GLV C/0(04/20/08) BP Exploration(Alaska) Loepp, Victoria T (DOA) From: Davies, Stephen F (DOA) Sent: Thursday,April 09, 2015 10:38 AM To: bradley.gorham@bp.com Cc: Loepp,Victoria T(DOA) Subject PBU 07-07C(PTD 214-175) Follow Up Flag: Follow up Flag Status: Flagged Brad, I'm Steve Davies,a geologist at AOGCC,and I am working with Victoria Loepp to evaluate BP proposed cementing operations for PBU 07-07C. While reviewing the geology in the Drill Site 7 area, I found that AOGCC's digital log files from the original well PBU 07-07(Permit 178-015,API 50-029-20295-00-00)are corrupt and unusable. I retrieved AOGCC's archive copy of those digital log files, but those archive files are also corrupt. Would it be possible for BP to provide AOGCC with a copy of the digital log file for PBU 07-07? The digital data that I need are MD,caliper,SP,GR, Resistivity, Neutron and Density. The paper log plots for PBU 07-07 begin at 2700' MD and extend down to 11,100' MD. Thanks for your help! Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission(AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 PV OF r4� • • y777kv THE STATE Alaska Oil and Gas , �� ofA TT Cc1 Conservation Commission 333 West Seventh Avenue 0 r r6 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 7r4Main: 907.279.1433 FALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Ken Allen Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-07C BP Exploration(Alaska), Inc. Permit No: 214-175 (revised) Surface Location: 1347' FNL, 138' FEL, SEC. 33, T11N, R14E, UM Bottomhole Location: 4283' FNL, 1709' FWL, SEC. 35, Ti 1N, R14E, UM Dear Mr. Allen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated November 4, 2014. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, f71e44‘/4 Cathy P Foerster Chair DATED this ey of March, 2015. =tisttV L:,LJ REVISEDLAOIL4. AND GAS CONSERVATION COMMON FEB 1 7 2015 PERMIT TO DRILL �+r� 20 MC 25.005 REVISED(Changer��s ram) 1 a.Type of work: 1 b.Proposed Well Class: ®Development Oil 0 Service-Winj ®Single Zone 1 c.Specify if well is proposed for: 0 Drill , 0 Lateral 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates 0 Redrill 0 Reentry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 2.Operator Name: 5.Bond ®Blanket 0 Single Well 11.Well Name and Number: BP Exploration(Alaska) Inc. Bond No 6194193 PBU 07-07C • 3. Address 6.Proposed Depth: 12.Field/Pool(s) P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 14115' ' TVD 8941' ' Prudhoe Bay/Prudhoe Bay - 4a.Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: ADL 028309&028308 ' 1347'FNL, 138' FEL, Sec.33,T11N, R14E, UM ' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2201'FNL,3287'FWL,Sec. 34,T11N, R14E, UM ' April 15,2015 Total Depth 9.Acres in Property: 14.Distance to Nearest Property: 4283'FNL, 1709'FWL, Sec.35,T11N, R14E, UM ' 2560 ' 25230' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 60.87' • feet 15.Distance to Nearest Well Open Surface: x 676067 • y-5949575 • Zone- ASP4 GL Elevation above MSL: 26.57' . feet to Same Pool: 200' 16.Deviated Wells: Kickoff Depth: 2750' feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 119 degrees. Downhole: 3321 • Surface: 2426 - 18. Casing Program Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 8-1/2" 7" 26# L-80 VamTop HC 6882' 2600' 2600' 9482' 8479' 855 sx LiteCrete, 91 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 VamTop 5165' 8950' 8009' 14115' 8941' 420 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 12870' 9054' 9584' 12760' 9040' None Casing Length Size Cement Volume MD TVD Conductor/Structural , 80' 20" 470 s Arcticset II 80' 80' Surface 2496' 13-3/8" 1600 sx Fondu,400 sx Permafrost'C' 2496' • 2495' Intermediate 9923' 9-5/8" 500 sx Class'G', 50 Bbls Permafrost'C' 9923' 8345' Production Liner 888' 7" 400 sx Class'G' 9621'-10509' 8143'-8773' Liner 3232' 3-1/2"x 3-3/16"x 2-7/8" 165 sx Class'G' 9565'-12797' 8104'-9043' Perforation Depth MD(ft): 11120'- 12756' Perforation Depth ND(ft): 9016'-9040' 20.Attachments: ®Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report ®Drilling Fluid Program 0 20 AAC 25.050 Requirements • 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct: Contact Brad Gorham,564-4649 Printed Name Ken Allen Title Engineering Team Leader Email Bradley.Gorham@bp.com Signature t.-- � Phone 564-4366 Date Y/-47/� Commission Use Only Permit To Drill API Number: Permit Approval Date: See cover letter for Number: 214-175 50-029-20901-02-00 \\ i•k(\L{ other requirements: Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas E'' contained shales: / Other: 36 p f-e s/- fp 5Z)D p 5 /,!_ Samples Req'd: 0/Yes 13/No Mud Log Req'd: ❑ es ['No 4!.-t n I. a r-p r6- / rpt ft v` / t51 h 2 J G�125'H2S Measures: [ Yes ❑)lo Directional Survey Req'd: L1f Yes 0 No Spacing exception req'd: ❑Yesrg No inclination-only svy Req'd: 0 Yes 13'No f� APPROVED BY 3'"((—/S - APPROVED - BY ^.ansAOrR THE COMMISSION Date Form 10-401 Revised 10/ 12 Thi i (a�7d cn�'{ n hs from the date of approval(20 AAC 25.005(g)) Submit Form and Atta ments In Duplicate Vri. 3/57/5- 0 , 2.. t9./S'— • 3F 0.40 • To: Alaska Oil & Gas Conservation Commission From: Brad Gorham, ODE Date: February 11, 2015 Re: 07-07C Permit to Drill Doyon 14 is currently scheduled to drill RST 07-07C, a horizontal Ivishak producer, in mid to late April 2015. A Permit to Drill was already submitted and approved on November 4th, 2014. However, there have been significant changes to the planned scope of work to necessitate a revised Permit to Drill. 07-07B has been P&A'd and the tubing was jet cut at -3,000' MD as per the approved Sundry. The 5-1/2" tubing will be pulled with the rig once it arrives on location. The revised plan is to cut and pull the 9-5/8" casing, run a 9-5/8" tieback and cement it back to surface. A 9-5/8" whipstock will then be set on an EZSV in the 9-5/8" casing at -2,766'. From there an 8-1/2" bit combined with the use of an underreamer will drill a 9" intermediate hole to the TSGR casing point. Moving forward a 7" liner will be utilized followed by a 6-1/8" production interval that will be completed with a cemented and perforated 4-1/2" production liner. The maximum anticipated surface pressure from the Ivishak/Sag with a full column of gas from TD to surface is -2,279 psi (assumes 7.13 ppg as max pore pressure and 0.1 psi/ft gas gradient). This well will be drilled by Doyon 14 using their 5,000 psi four preventer BOP stack A detailed operations summary is included with the permit application. Below is a brief summary of planned drilling operations. 1. Move in and rig up Doyon 14 2. Nipple up BOPE and test to 3,500 psi 3. Pull 5-1/2" tubing from -3,000' MD to surface 4. RU e-line and run USIT/CCL/GR. 5. Set EZSV at-2,775' MD and test to 3,500 psi. 6. Cut and pull the 9-5/8" casing from 2,300' MD. 7. Tieback and cement 9-5/8" casing back to surface. 8. ND BOP and PU tubing spool and install slips on casing head 9. Test 9-5/8" seals and void 10. NU BOP and test breaks to 3,500 psi 11. MU clean-out BHA and perform clean out run to top of EZSV. 12. PU and set whipstock at-2,766' MD. (End of Sundry/Beginning of PTD) 13. Mill window in 9-5/8" casing. Perform LOT. 14. Drill 9" intermediate section with 8-1/2" bit and underreamer to TSAG casing point 15. Run and cement 7" liner (TOC will be -700' TVD above West Sak/Ugnu). Pressure test to 3,500 psi. 16. Drill 6-1/8" production interval to target Zone 2B sands. Geosteer as required. 17. Run and cement 4-1/2" production liner (TOC will be top of 4-1/2" liner top packer). Pressure test to 3,500 psi. 18. Run in hole with perforating assembly. Perforate 4-1/2" liner only after cement has reached 1,000 psi compressive strength. 19. Run 4-1/2" production tubing. Set the production packer and pressure test to 3,500 psi. 20. Freeze-protect and secure well. 21. Rig down and move off Doyon 14. In addition to a planned well summary, directional plan with anti-collision report and proposed completion diagram is attached to the permit application. If there are any questions concerning information on 07- 07C, please do not hesitate to use the contact information below. 07-07C PTD Page 1 2/11/2015 • S Brad Gorham Office: 907 564-4649 Cell: 907 250-3209 Email: Bradley.GorhamCa bp.com Attachments: 07-07B Wellbore Schematic 07-07B Proposed Pre-Rig Schematic 07-07C Proposed Completion Directional Plan Anti-collision Report As-Built Survey BOPE Equipment Schematics Well Head Schematic Tree Schematic Planned Well Summary Well 07-07C Well Producer TarObjective et Ivishak Current Status 07-07B is currently shut-in due to high GOR Estimated Start Date: 4/15/2015 Time to Complete: 33.4 Days Surface Northing Easting Offsets TRS Location 5,949,574.79 676,067.20 1,346.95' FNL / 11N 14E sec 33 5,141.7' FWL Tie in Northing Easting Offsets TRS (Sidetrack 5949608.38 676065.78 1,313' FNL / 5,141.1' 11N 14E sec 33 point) FWL Northing Easting TVDss Offsets TRS Tgt 1 5,948,823.00 679,448.00 -8,474' 2,178.7' FNL / 3,222' 11N 14E Sec TSGR FWL 34 TSAD 5,948,802.00 679,513.00 -8,578' 2,201.3' FNL / 11N 14E Sec 3,287.0' FWL 34 BHL 5,946,810.00 683,267.00 -8,880' 4,283.1' FNL / 11N 14E Sec 1,709.3' FWL 35 Planned KOP: • 2,750' MD / 2,687' Planned TD: 14,115' MD / 8,880' TVDss TVDss Rig: Doyon 14 GL-RT: 34.30 RTE (ref MSL): 60.87 07-07C PTD Page 2 2/11/2015 • • Directional - Schlumberger P2 KOP: 2,750' MD Maximum Hole Angle: 33.93° in the 8-1/2" intermediate section 119.07 in the 6-1/8" production section 02-06, 02-06C, 02-26, 02-26A, 02-26APB1, 02-26APB2, 02-26B, 02-26C, Close Approach Wells: 07-02, 07-07 -91' MD to -2,750' MD = GYD-GC-MS Survey Program: -2,750' MD to 3,100' MD = INC+TREND 3,100 MD to TD = MWD+IFR+MS-WOCA Nearest Property Line: 25,230' Nearest Well within Pool: -200' Formation Tops & Pore Pressure Estimate (SOR) Estimated Minimum Most Likely Formation Formation Top Pore Pressure Pore Pressure ;: (TVDss) (EMW ppg) (EMW ppg) L ' SV5(Above 2,619 8.35 8.40 Plan) Nt C;,, �' �` KOP 2,687 8.35 8.40 1 -6 SV4 2,738 8.35 8.40 Ole. SV3 3,282 8.35 8.40 SV2 3,513 8.35 8.40 SV1 3,883 8.35 9.70 UG4 4,454 8.35 9.70 UG3 4,692 8.35 9.70 UG1 5,145 8.35 9.70 WS2 5,781 8.35 9.70 ` ' WS1 5,951 8.35 9.70 1` t,,1' A CM3 6,128 9.20 , 9.50 v C yl oa a bade }yOr�{4 _ CM2 6,663 9.30 9.80 Vlcty/w5«/c D CM1 7,369 . 9.40 10.00 THRZ 7,758 9.60 10.00 BHRZ 7,927 9.60 10.00 TPTR 8,013 6.69 9.16 BPTR 8,033 6.69 9.16 LCU 8,033 9.60 10.00 TJC 8,033 9.60 10.00 TJB 8,222 9.60 10.00 TJA 8,320 9.60 10.00 TSGR 8,414 - 5.71 7.13 TSHU 8,450 6.90 7.13 TSAD 8,518 6.92 7.13 TCGL 8,694 6.92 7.13 BCGL 8,767 6.92 7.13 23SB 8,826 6.92 7.13 22TS 8,879 6.92 7.13 07-07C PTD Page 3 2/11/2015 • • 21TS 8,929 6.92 7.13 PGOC 8,958 6.92 7.13 HOT 8,990 6.92 7.13 TZIB(Below 9,006 6.92 7.13 Plan) Invert 8,987 Cross Fault 8,987 TDF(Below 8,997 6.92 7.14 Plan) TZ1B 9,000 6.92 7.14 Final Invert 9,000 (Toe) 21TS 8,958 6.92 7.14 PGOC(Toe) 8,930 6.92 7.14 22TS 8,914 6.92 7.14 23SB(Above 8,870 • 6.92 > 7.14 Plan) Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. MD/TVDss MD/TVDss 8-1/2" 7" 26 L-80 VamTop HC 9,482'/8,418' 6-1/8" 4 %" 12.6 13Cr-85 VamTop 5,165' 8 950'/7,948' 14,115'/8,880' (-150' lap) Tubing 41/2" 12.6 13Cr-85 VamTop 8,955' Surface 8,95577,950' (-5' into liner TBS) Mud Program Intermediate Mud Properties: LSND 8-1/2" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (ppg) KOP-3,650' MD 9.2 - 9.7 ' <17 18 -25 <8 NA <18 9 - 10 3,650' MD -7,300' MD. 9.7 - 10.0• <17 18 -24 <8 NA <20 9 - 10 7,300' MD -9,482' MD. 10.2 - 10.4 - <20 18 -24 <4 <10 <20 9 - 10 Production Mud Properties: Water Based Polymer Fluid (PowerPro) 6-1/8" hole section Density PV YP Low Shear Depth IntervalAPI FL Rate MBT pH (ppg) (cp) (Ib/100ft2) Viscosity 9,482' MD -TD - 8.4 -8.8 <12 10 -20 <10 >15,000 <4 8 - 10 Logging Program 8-1/2" Intermediate: Sample Catchers-as required by Geology Drilling: Dir/GR/Res Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers-as required by Geology Drilling: Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None 07-07C PTD Page 4 2/11/2015 • • Cement Program Casing Size 7"26#, L-80 VAM TOP HC, Intermediate Liner Basis: Lead: Annular volume plus 40% excess, 80' shoe track Lead: TOC: 3,350' MD (-700' TVD above the Ugnu/West Sak DPZ) Tail: A tail slurry will be utilized due to the ECD's that will be induced on the cement job. Total Cement Spacer —45 bbls of Viscosified Spacer weighted to —11.5 ppg (Mud Push II) Volume: Lead 178.2 bbls, 1,000.08 ft', 854.8 sacks, 11.5 lb/gal LiteCRETE H- 1.17 ft'/sack Tail 17.7 bbls, 99.37 ft', 91.4 sacks, 15.8 lb/gal Class G- 1.17 ft'/sack Temp BHST 191° F Casing Size 4-1/2" 12.6#, 13Cr-85 VamTop, Production Liner Basis: Lead: Annular volume, 80' shoe track Lead: TOC: 8,950' MD (Top of 4-1/2" liner) Tail: None planned Total Cement Spacer —50 bbls of Viscosified Spacer weighted to —11.5 ppg (Mud Push II) Volume: Lead 87.6 bbls, 491.83 ft', 420.4 sacks 15.8 lb/gal Class G— 1.17 ft'/sk Temp BHST 197° F Surface and Anti-Collision Issues Surface Close Proximity: No wells will be affected by the Doyonl4 rig shadow. See below for shut-ins due to close approach. Sub-Surface Pressure Management: No wells will need to be shut-in due to pressure interactions. Anti-Collision: Nine Wells fail major risk but only three wells will need to be shut-in while drilling: ➢ 02-06B— P&A'd due to sidetrack ➢ 02-26 - P&A'd due to sidetrack ➢ 02-26A/02-26APB1/02-26APB2 - P&A'd due to sidetrack ➢ 02-26C—effectively P&A'd as a CIBP was set at 12,515' MD and passed a PT. Since our potential intersection point is 12,890' MD, this well will no longer need to be shut-in. ➢ 07-02 -will need to be shut-in at surface prior to drilling out the 07-07C 7" shoe track and will need to remain shut-in until the production liner is cemented in place. ➢ 07-07—P&A'd due to drilling of parallel well 07-07A. Hydrogen Sulfide DS-07 is not considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Date of Reading Parent Well (if sidetrack) 07-07B #1 Closest SHL Well H2S Level 07-06B 20 ppm • 3/31/2013 #2 Closest SHL Well H2S Level 07-08B 22 ppm 2/2/2014 #1 Closest BHL Well H2S Level 07-02B 28 ppm 3/31/2014 #2 Closest BHL Well H2S Level 02-06B 14 ppm • 2/12/2014 #3 Closest BHL Well H2S Level 02-26C 20 ppm 5/20/2014 #4 Closest BHL Well H2S Level 02-25A 22 ppm • 1/30/2012 Max Recorded H2S on Pad/Facility 07-24 50 ppm • 5/15/2005 07-07C PTD Page 5 2/11/2015 # • Faults Throw Formation Where MD TVDss Direction Uncertainty Lost Circ Encounter Fault Intersect Intersect and Potential Magnitude Fault#1 -Z2C 10,010.0 8,818.0 10-15'DTE 100' Low Fault#1 -Z2A 11,065.0 8,988.0 50-70'DTW 100' Low Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal/Contact the GPB Environmental Advisors (659-5893)f/guidance. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP test frequency for 07-07C will be 7 days during the de-complete phase. After a successful casing test and during the drilling phase, a full BOP test will occur every 14 days with a function test occurring every 7 days. Except in the event of a significant operational issues that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Intermediate Interval Maximum anticipated BHP 3,121 psi at the TSGR at 8,418' TVDss (7.13 ppg EMW) Maximum surface pressure 2,279 psi (.10 psi/ft gas gradient to surface) ✓ 25 bbls with 13.1 ppg frac gradient Kick tolerance Assumes 7.13 ppg pore pressure in the TSGR + 0.5 ppg kick intensity and 10.2 ppg MW. Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 3,500 psi/250 psi 7" Casing 3,500 psi surface pressure Integrity Test—8-1/2" hole LOT after drilling 20'-50' from middle of window The 7" Casing Rams will be installed once the 9-5/8" casing cut and pull 7" Casing Rams is completed and will remain in the upper rams until the production interval. Production Interval Maximum anticipated BHP 3,321 psi at the PGOC at 8,958' TVDss (7.13 ppg EMW) Maximum surface pressure 2,426 psi (.10 psi/ft gas gradient to surface) ✓ Infinite with >9.3 ppg frac gradient Kick tolerance Assumes an 7.13 ppg max pore pressure in the Ivishak+ 0.5 ppg kick 07-07C PTD Page 6 2/11/2015 • • intensity and 8.6 ppg MW. Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 3,500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20'-50' of new hole 4-1/2" Liner Top Packer 3,500 psi surface pressure Planned completion fluids 8.4-8.5 ppg Seawater 07-07C General Operations Summary Proposed Drilling Rig Operations: 1. MIRU Doyon 14 2. Test TWC from below to 3,500 psi for 5 minutes. 3. Nipple down tree. Nipple up and test BOPE to 3,500 psi.(9-5/8" FBR's in upper cavity and 3-1/2" x 6"VBR's in lower cavity) 4. Pull TWC with lubricator. 5. RU hard lines to BOP. Circulate out diesel freeze protection and displace well to clean seawater. 6. RU and pull the 5-1/2" tubing from the pre-rig cut. 7. PU and RIH with 9-5/8" clean out assembly down to the top of tubing stub. 8. RU E-line and RIH w USIT/CCL/GR and log from the tubing stub to surface to determine: • KOP • Cement behind casing at KOP. • TOC behind the 9-5/8" casing for cut interval. • Casing collar locations. 9. RIH with EZSV, GR/CCL log and set EZSV as required to avoid cutting a casing collar. Rig down E-line. 10. Pressure test the EZSV to 3,500 psi for 30 min. Chart test. 11. MU a 9-5/8" Baker multi-string cutting assembly. Cut the 9-5/8" casing above TOC as determined from USIT log. POOH and LD cutting assembly. 12. MU 9-5/8" casing spear assembly, RIH and unseat the 9-5/8" casing and circulate out freeze protect(arctic pack). 13. Pull and LD the 9-5/8" casing. 14. RIH with casing scraper and clean-out the 13-%" casing and dress off the 9-%" casing stub. 15. Run new 9-5/8", 47#casing w/Bowen patch, ECP and ES-cementer. Land patch over the 9-5/8" stub and pull 100K over string weight and fully cement the 9-5/8" casing in place as per the wellplan. 16. Continue to hold the 100k over-pull on the 9-5/8" casing until the cement reaches sufficient compressive strength. 17. Split the stack above the casing spool and set the casing on slips. 07-07C PTD Page 7 2/11/2015 • • 18. Cut the 9-5/8" casing using Wach's cutter and LD excess casing. 19. Install packoff and NU wellhead to include new tubing spool. 20. Test packoff. 21. NU BOP on the new wellhead and test breaks to 3500 psi. (Install 7" FBR's in upper cavity). 22. MU clean-out 8-1/2" BHA and drill-out ES Cementer and cleanout to the 9-5/8" EZSV at 2,775' MD and test the well to 3,500 psi. 23. PU 9-5/8"whipstock, bottom trip anchor and 8.5"window milling assembly(to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. 24. Swap the well over to 9.0 ppg fresh water LSND milling fluid. 25. Mill window in the 9-5/8" casing plus 20' of formation. • 26. Pull into 9-5/8"window and perform LOT. POOH for drilling BHA. 27. MU 8-1/2" 1.5° motor BHA with GR/RES/PWD and RIH. Drill -800' of 8-1/2" intermediate interval. 28. POOH and LD 8-1/2" 1.5° motor BHA. 29. PU PDX6 RSS with 8-1/2" bit and underreamer and drill 9" intermediate interval to section TD in TSGR. Weight up drilling fluid using spike fluid following the PPFG density ranges. 30. At TSGR, CBU until hole is clean (minimum 2x) and perform short trip to the window. 31. RIH to TD, circulate well clean, and POH on elevators. 32. Run 7", 26#, L-80, VAM TOP HC liner to TD, set liner hanger and liner top packer. 33. Cement 7", 26#, L-80 VAM TOP HC for zonal isolation. Circulate out cement with mud. POOH. 34. Change upper 7" casing rams to 2-7/8" x 5-1/2"VBR pipe rams and test to 250 psi low/3500 psi high. 35. MU 6-%8" drilling BHA with GR/RES/NEU/DEN. RIH to the landing collar and test the liner to 3500 psi for 30 minutes. 36. Displace the well to 8.6 ppg Power-Pro SF fluid prior to fully drilling out shoe track 37. Drill out the 7" shoe plus 20' of new formation. Pull into the shoe and perform a FIT. 38. Drill 6-1/8" production hole to TD as per directional plan. 39. Circulate bottom ups and condition the hole as necessary. 40. Short trip BHA to 7" shoe pulling on elevators 41. Trip in hole to TD and circulate/condition the hole as necessary until shakers clean up. POOH on elevators. 42. MU and run 4-W 12.6# 13CR VamTop liner to TD. 43. Fully cement the liner to the TOL with 15.8 ppg Class G cement. 07-07C PTD Page 8 2/11/2015 • S 44. Set liner top packer and displace well to clean seawater above the liner top. 45. Pressure test casing and liner to 3,500 psi for 30 minutes. 46. POH, L/D the liner running tool. 47. RU DPC perf guns, RIH and perforate. 48. R/U and run a 4-%2", 12.6#, 13CR, VAMTOP tubing completion with GLMS. Space out and land the tubing with tubing tail inserted into the liner tieback sleeve. 49. Space out and make up tubing hanger per Cameron Rep. Land the tubing hanger, and run in lock down screws. 50. Displace tubing and IA to 8.8 ppg brine and reverse circulate with corrosion inhibitor(surface to surface). 51. Drop ball and rod. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 52. Shear the DCR valve. 53. With landing joint still rigged up, reverse circulate diesel freeze protect using rig injection pump. 54. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. 55. Install TWC and test from above to 250 psi low/3,500 psi high for 5 minutes each and from below to 250 psi low/3,500 psi high for 5 minutes low/5 minutes high. 56. Nipple down the BOPE. Nipple up the adaptor flange and double master valves and test to 5,000 psi with diesel. 57. Install all annulus valves and secure the well. 58. RDMO. Planned Post-Rip Operations: 1. MI/ RU Slickline. Pull TWC, ball and rod and RHC Plug. 2. Pull shear valve and dummies, install GLVs. 3. Obtain SBHP 4. Flowback per ASRC 5. Modify S-Riser as required. 6. Install flow lines and well house. 07-07C PTD Page 9 2/11/2015 • • 07-07C Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. Intermediate Hole: Possible overpressure in the Put River formation. The PPFG will be strictly followed to mitigate the overpressure if it is encountered. B. Production Hole: The Ivishak is expected to be at a 7.13 ppg EMW. Reservoir pressures will be controlled by using 8.4-8.8 ppg water based mud thought out the production interval. II. Lost Circulation/Breathing A. Intermediate Hole: There are no expected fault crossings in the intermediate hole section. Be aware of drilling ECD's as recent wells have encountered breathing in the intermediate section. B. Production Hole: Two fault crossings are planned in the production hole. Lost circulation is considered a low risk as other wells have crossed these faults and had minimal history of lost circulation. . III. Fault Locations Formation Where MD TVDss Throw Direction Lost Circ Encounter Fault Intersect Intersect and Magnitude Uncertainty Potential Zone 2C 10,010.0 8,818.0 10-15' DTE 100' Low Zone 2A 11,065.0 8,988.0 50-70' DTW 100' Low IV. Integrity Testing Test Point Test Depth Test type EMW(lb/gal) 9-5/8"window 20'-50' from the 9-5/8"window LOT 13.1 ppg 7" shoe 20'-50' from the 7" shoe FIT 9.3 ppg V. Hydrogen Sulfide A. DS-07 is not considered an H2S site. Recent H2S data from the Pad is as follows: Well Name H2S Level Date of Reading Parent Well (if sidetrack) 07-07B #1 Closest SHL Well H2S Level 07-06B 20 ppm 3/31/2013 #2 Closest SHL Well H2S Level 07-08B 22 ppm 2/2/2014 #1 Closest BHL Well H2S Level 07-02B 28 ppm 3/31/2014 #2 Closest BHL Well H2S Level 02-06B 14 ppm 2/12/2014 #3 Closest BHL Well H2S Level 02-26C 20 ppm 5/20/2014 #4 Closest BHL Well H2S Level 02-25A 22 ppm 1/30/2012 Max Recorded H2S on Pad/Facility 07-24 50 ppm 5/15/2005 VI. Anti-Collision Issues Nine Wells fail major risk but only three wells will need to be shut-in while drilling: ➢ 02-06B-P&A'd due to sidetrack ➢ 02-26 -P&A'd due to sidetrack ➢ 02-26A/02-26APB1/02-26APB2- P&A'd due to sidetrack ➢ 02-26C -will need to be shut-in at surface prior to drilling out the 07-07C 7" shoe track and will need to remain shut-in until the production liner is cemented in place. ➢ 07-02-will need to be shut-in at surface prior to drilling out the 07-07C 7" shoe track and will need to remain shut-in until the production liner is cemented in place. ➢ 07-05-will need to be shut-in at surface prior to drilling out the 07-07C 7" shoe track and will need to remain shut-in until the production liner is cemented in place. ➢ 07-07- P&A'd due to drilling of parallel well 07-07A. CONSULT THE DS-07 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 07-07C PTD Page 10 2/11/2015 TREE WELLHEAD GRAY GEN 3 • 07-07B S o V�ELLt1-1,D= (,Rqy SA TES; WELL 70 @ 151833'. ACTUATOR= AXF3.SON MAL KB.ELE 64' . KOP= 2800 20"CONDUCTOR, 1— 2130' 1--5-i/2"CAMCO 8AL-0 Sssv rF D=4.562" Aix Angle= 95'@ 11018' 91.5#,1-40, 0>tatun M)= 10633' D=19.124" s GAS LLT MANDRELS Datum TVD= 8800'SS — J ST MD TVD 0EV TYFE VLV LATCH PORT D1ATE- HALBUR7'ON DPW PATCH, -1102'-1122' 1 2897 2893 14 MNG OW RK 0 0420f48 2 5049 4727 36 MbG DMY RK 0 0420+08 D=2.987"(10129/08) 3 6676 5962 43 MAG (MY RK 0 03/30/83 13-3/8"CSG,728,1-80,ID=12.347' 2496' 4 7837 6833 40 MIUG OMI' WC 0 03/30/83 1 _ 5 7902 6883 41 WAG CMI' Rt( 0 03/30+83 6 8522 7349 43 MAG CMI' RK 0 03/30/83 HALEURTON DPW PATCH,D=2.98r —16894'-6914 1 L1 (SET 10/29/136) 7 8594 7402 43 MuiG 0114W RK 0 03/30/83 8 9043 7729 43 4G DMV RK 0 03/30/83 9 9114 7781 43 MAG MY RK 0 03/30183 10 9428 8007 44 MAG DMY RK 0 03/30+83 Minimum 10= 2.377"@ 10928' 11 9501 8059 45 MAG DMV RK® 0 03/30+83 3-3/16"X 2-718"XO II i1 9565• 4"ROT DH'LOY SLV w/GS PROF,D=3.00 ...., ,.. 9571' H4"X3-1/2" X0.113=2.977' 9575' 5-112'BKR PBR ASSY(BE NNID PiPI 9581' /8'X 5-1/2"BIR SAB PIN(BEHIND PIPE)1 �►.,r'+' t_ 9684' '—I 3-1/2'PX PLUG(04/19/13) 1 =2 1 5-112'TBG-Pc,17#,L-80,.0232 tspf,D.4,89-2;71.1 9592' j--- 9584' j. 3112"HCNiYCOX NP,D813' -- -----'"^- 9592' _J5-1,2'X4-1/2"XO(B@NniaPNPEI j 13-1/2"LNR,9.2#,L-80,STL,.0087 bpi,13=2 9921--1 9614' 1 9614' —3-1/2'X 3-3116'XO,D=2.786' 1 TOP OF r uRJ--[ 9621' j 9652' 4-1/2"CAMCO DB-6 NSP,D=3.813' I ill 9663' H4-12'BKI SHSAROUT SUB Boom4-1/2"113G-FC,12.bY1.L-80..0152 bpf.0=3.958' 1� 9 9964' 1---{a 1/2"TLENNG TAL,D=4.00' PIPE 9-518'CSG,47#,L-80,D=1.68121-1-9-9-2-in `. 1 9657 H E-MO TT LOGO 05/28/89 I Mgr Vii; 10325'25 EST TOP OF CEMENT I •i•• •�• (7'MECHANICAL W-IPSTOC K(0621/06) 10610' ' %i �4 N, LOUT WINDOW(07.076) 10509'-10514° •i•, ip 10621' `�4`. ..1ii11 iii+l 1,+► 10928'P—33116"X 2-7/8" XO, viii+iiia, +i+ii••, D=2377 • PI FoRATiOIV SUN *+a+#++++iii C24 REF LOG-MJ CCU/GR ON 06/28/06 +♦++4,4 ANGLE AT TOP PEW 92' 11120' ••••••••• -•••••ilii• 12760' PBTt3 +44514 Note:Refer to Production DB for historical pert data •••••• li♦ •SIZE PIIHZVAL n —._ -_ :MX - �..` 0P 1Sgz SHOT SC3Z ill•••l•4< 3-3118"LNR 6.2A<,L-80, 100?8' SEE PAGE 2 FOR PH2FORATiDN DATA 6••••••5.4!5 Ism,.0076 bpf.D=2.80' _�_� iiiii4• 4.4555 -40 iil4+ii44Or 2-718"OR 8.16#.1-60. 1279T� .5+4+4.4+i/i STL,.00S8 bpf,D=2.441" Ri5+i& ♦�f��f 7"LIR,29#,VL-80,.0371 bpf,D=6.184' --1 10947' i 14444F 4rilrl 12870' DATE REV BY'- COMVENTS DATE REV BY COMMENTS FEIJOHOEBAY UNIT 03/31/83 NNTIAL(07-07A) 10/21/14 PJC CONDUCTOR CORRECTION WELL: 07-0713 06/30/06 NORDIC 1 CTD(07-078) 10/21/14 TR/JMD MSC CORRECTIONS PBTMT No:i' 060810 10/13/08 JIQYPJC SET PATOIS(09/29/08) AR No: 50-029-20901-02 03/18/10 OP /SV SET PX PLUG(03/10/10) _ SEC 33,T11N,R14E 1347'RC&138'FE., 10/02/12 TIJJMD PATCH CB'TH CORRECDONS —04/25/13 MSS/JMD RUN PX PLUG(04/19/13) BP Exploration(Alaska) • • 07-07B r r . . . .0L. Ii L z r4 IN 1 f F'FWORATION SUMMARY . ►,+; REF LOG: ti CCU GR ON 06/28ros . ►;.� II ANGLE AT TOP PERE:92"@ 11120 ... Note:(defer to Production DB for historical peri data `•`{•.. SIZE SPF t41H VAL Opn/SqzSHOT . SQ2 `4. 2 6 11120-11170 0 06/29/06 ..«i•�«i«ii•4 >i..11,414,,4 2 6 11210-11330 0 06/29/06 ps•••• 2 6 11380-11510 0 06/29/06 iii.•«•«•i«� 2 6 11590-11920 0 06/29/06 *.•i•««.«i+ 2 6 12040-12200 0 06/29/06 ,.•iiiilk••IV• ;.iiii+ii:44. 2 6 12250-12600 0 06/29106 ,+«.•i*.•«� 2 6 12690-12756 0 06/29/06 iii+rr r 414%0 'oo"«I«ii•*1 4+:4 0,- *«4-}*i«.«.iii* «,i•,•••41104,4 ;1440 0❖i•..•••4 �ai•,.•a•�•i 'i'i'ire ri0 .iaf'.i.i"' I—IT—ATEREV BY COMMENTS DATE REV BY COMMENTS PRiJDHOEBAY UNfT 03/31/83 INITIAL(07-07A) ,10/21/14__PJC CONDUCTOR CO TiON WELL: 07-07B 08130/06 AR CC(CTD(07-07B) �10C21/14 TR/JM) MSC CORRECTIONS PERMIT No:"2060810 10/13/08 JKLYPJC SET PATOIS(09/29/08) APi No: 50-029-20901-02 03/18/10 OPIJSV SET PX PI UG(03!10/10) SEC 33,T11N,R14E,134T F &138'FB.. I 10/02/12 TUJM) PATCH DEPTH CORRECTIONS 04/25/13 MSS/JMJ RUN PX PLUG(04/19/13) BP Exploration(Alaska) 1REE= GRAY GEN 3 WELLHEAD= GRAY 07-07B SAFES/107ES: WELL 70°Q 10833'. • ACTUATOR= AXELS014 PROPOSED P&A IttnAL KB.ELE 6,4. BF.ELEV= ? I .KOP= 2800' 20^comucToR, --jr- -80 Max Angle-= 95'©11018' 91531,1449, Datum NU= 10633' ID=19,124" rill Ntum TVD= 8800'SS HALEURTON DPW PATCH, 1-11102' -1122" l 0.2.98r(10129108) I -3,000 Jet Tubing Cut 13-3/8"CSG,72#,L-80,13=12347- H 2496' , HALEURTON OFW PATCH,ID=2.98r --1 6894'-6914' (SET 10/29/08) Proposed TOC — -8,500 H4-Bar DEPLOY SLV w/GS FROF,ID=3.00 Proposed TOC —9,8,517 9671' -I4'X 3-1/2" XO,13=2.972" 4 c " 1" ' 9575° H5-1/2"BKRFBR ASSY au PIPE) - I 9581"A-19-5/8-X 5-112-BKR SAB P(R(BEHIN)PIPE) 1 Z . . 1 ,, 9594' -13-112-PX PLUG(04/19/13) 0 5-1/2"TI3G4PC,17#,L-80,.0232 bpr,0=4.892- H 9592' 1 A , 9584" 1-I3-u2"Hamm X NIP,D;;;2813r71 9692' H5_112-x 4-1/2"XO(BEHIN)PIPE) 3-1/2"LNR,921t,L-80,STL,.0087 bpf„ID=Z992" H 9614' w -4----"----1 9614' H3-1/2'X 3-3/16"XO,E)=2186" TOP OF r UV H 9621' —1 — I I ' 9952. H4-i12"ciokio0.0B-6 WI,63=3.813" ., le 9663' 1-14-112-BKR SHEAROUT sLe 13E190 4-1/2"TI3G-FC,12.6#„L-80,.0152 bpf,0=3.958- H 9664 , # . 9664" H4-1/2-TUBING TAL,ID=4.00' PIPE 9-5/8"CSG,47/1,1-80,ID=8.681" H 9923' I-41 965T H aMD 11 LOGGGED 05/28/89 4 10325' j-i EST TOP OF CDIAENT I •-• •• • •• •• • • •• •• • MALUXIII WINDOW(07-0713) 10516'-10524' 7^MECHANICAL WHPSTOCK(06/20/08) 10511' 1.110 4. 4 '*•,..., RA FIL1YTAG -I_10521' ** 474/.•4 I r4i l 10928' -3-3/18*X 2-7/8" XO, ••••••• •••••• ••••••. ID=2.377" •••••4" •••••• PERORATION SUAROARY ••••••4 •••••• •••••4- •••••• REF LOG:EtICNU CCU GR ON 0603/06 •••••4 11.••••• -- ••••••4. R ANGLE AT TOP FEW 92"@11120' 12767 --IEITD•••••• •••••4 •••••• ,.- ***** •••••4. Note:Refer to Production DB for historical perf data _ •••••• ••••••4 •••••• SEE I SPF I 1YTERVAL I-Opri/Sgz I SI-DT 1 SQZ .4.4.4.4.V. 3-3/16"LNR,6.2#,L-80, 109287.1 ir - •••••4 *••••• SEE PAGE 2 FOR PERFORATION DATA •••••4 STL,.0076 bpi,ID=2.80" •••••• V. 1 1 I ,•••••4 0••••• •••••1 o••••• •••••4. *••••• 2-7/8"I_NR,6.18#,L-80, --F 12797' — - •••••4 •••••• STI,.0058 bpf,D=2.441' •••••• .A.A.,....at g 11.W.e.711.41.•'i. 7"LMR,29#,L-80,.0371 bpf,U=6.184' -1_, 10947' r...........4 #............t TD 12870' DATE REV BY COM DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/04/79 ORIG COMPLETION 10/13/08 JKD'PJC SET PATCHS(09/29/08) WEI.L: 07-07B 03/31183 LAST WORKOVER * 03/18/10 OPC/SV SET PX PLUG(03/10/10) — FERMI No: 2060810 06/30/06 NORDIC 1 CTD("B") 10/02/12 TUJEEI PATCH DEPTH CORRECTIONS AR No: 50-029-20901-02 07/04/06 KSB/PAG GLV CIO 04/25/13 PS/JM)RUN PX PLW(04/19/13) SEC 33,T11N,R14E.1333'FM_&142'FEL 03/03/07 DRF/PJC ORLG DRAFT CORRECTIONS 02/07/14 PJC ADO CONDUCTOR INFO 04/30108 Cil/SV GLV C/O(04/20/08) BP Exploration(Alaska) ____ • 07-07B 'a C ' 0 , :_ L Vii at I 4 PERFORATION SANWARY ;:: s .. • RFF LOG:Mtn/CCL/GR ON 06/28ro6 •• •: •• ANGLE AT TOP PEW:92°@ 11120' 3 �• Note:Refer to Production DB for historical perf data •.`0,. SIZE SW F1TH VAL Opn/Sqz SHOT SQZ 2 6 11120-11170 0 06/29/06 1•�•�•�•�•e4 �•i••• ••4 2 6 11210-11330 0 06/29/06 P••••••••••• 2 6 11380-11510 0 06/29/061.••••••• •• 2 6 11590-11920 0 06129/06 •i�i�i•i•i� 2 6 12040-12200 0 06/29106 r••••♦ 2 6 12260-12600 0 06/29/06 ,•�•�•�•�•.•' ••••••• 44004p 44104P2 6 12690- 12756 0 06/29/06 r•�••••••••• ♦••••♦ 400, 414. •555SSi vemem O AA AAA AAA ...... .. .... .......... . DATE RPI BY * COM\IENTS GATE REI/BY C OMA:NTS PRUDHOE BAY UNIT 01/04/79 ORIG COMPLETION 10/13/08 JKIYPJC SET PATCHS(09/29/08) WELL: 07-078 03/31/83 LAST WORKOVB2 03/18/10 OPC/SV SET PX PLUG(03/10110) PERMT No: 2060810 06/30/06 NORDIC 1 CTI)("B") 10/02/12 Tl2JM) PATCH DEPTH CORRECTIONS API No. 50-029-20901-02 07/04/06 KSB/PAG GLV 0O 04/25/13 MISS/JM)RUN PX PLUG(04/19/13) SEC 33,T11N,R14E, 1333'FN.,&147 FEL 03/03/07 DRF/PJC DRLG DRAFT CORRECTIONS 02/07/14 PJC ADD CONDUCTOR INFO L04/30108 CJN/SV GLV CJO(04/20/08) BP Exploration(Alaska) Tim= t1RAY(B13 0 / -0�� IILL E D-- ' PROPOS._ ANCTES: ATRIA OR= AMMO l II Hf`V= 70' I III BF HEY= a __"CXADU T R 7 I H4-1/2"HESXN NIP, ID=3.813" BOP= 21100' ..�4 I Mac Aagb= +19fa99G0r D- • 2352' f-- Full Open Collar pain1yp= 2300'-- 9-5/8" Cut& Pull IL-- 2478' 1— Full Open Collar 13-3/8"CSG,72#, L-80 ID= 12.347" 2496' 9-5/8"WHIPSTOCK(_/_/—) --2750' ' -2600' —ITOP OF 7"LNR 9-5/8"CSG,47#, L-80, ID=8.681" H-2759' 9-5/8"EZSV, (_/_/—) I—-2775' MILLOUT WINDOW(07-07C) 2739 -2749 *."` GAS LFT MANDRELS ST i MD TVD DEVs TY FE VLV LATC1-I R)RT DATE TOP OF CEMENT(3260')ND 1-1-3350' I r, 4 61 i. 2 � r HALLIBURTON ES CEMENTER I--6,900' ' ti I-4-1/2"HES XN NIP, ID=3.813" BAKER ECP l—-6,950' t!+ Li, ,1 to -9200' 7"X 4-1/2"HES TNT PKR, ID=3.870" n - 4 P1 4-1/2"HES XN NIP, ID=3.813" y ' y I-4-1/2"HES XN NIP, ID=3.813" 1 4-1/2"TBG, 12.6#,13CR-85 VAM TOP, .0152 bpf,ID=3.958" - -9327' .fitil I, 1 L. I 1 --9322' 7"X 5"BKR TIEBACK SLV, ID= " TOP OF 4-1/2"LNR CEMENTED -9332' A " . -9327'—14-1/2"WLEG, ID=3.958" t 4 4 _9332 --17"X 5"BKR ZXPN LTP,ID= " !;y. kA' ---5"X4-1lt X0,ID- 7"LNR,26#,L-80 VAM TOP HC,.0383 BPF,ID=6.276" I— !# ..0 -9482' RA TAG { T r '1 1:10 NiF111.1 %P. 1 ;1' r REFFORATION StJRfiAA Rf 10. 40! Rff LOO, ON 1 / tai ANGI FATTOPFFRP s'fp IIP1 te:Refer to Roducticn IS for historical perf data s 51 LE ST i- NI ERVAL t]pn'Sgz HU I 1 SU H RA TAG titIIIII y 1 , 1111 i ;1 t r4v4v v4 iN PBTD f1I444444444N t►14444444.�` I-14,115'I_ 4-1/2"LNR, 12.6#, 13CR-85 VAM TOP, .0152 bpf, ID=3.958" DAIL Fri EY COMM NTS 1346CL. REV 5Y CONLENTS F UGHOL BA" 111I 01111.1/79 ONG COMPLETION 10/1.3'DB' JQaPJG ZLTPATts I0912908) WELL: 07-070 03131/83 LASTWORI4)VBi 05+18&0' OP PSV SET PXPan t021t10f'10) PB3hIT41 20841813 ow= NOBLIG1 CTD(•W) 1&u i12 LivM I=A lf.alL PII1t)U111I IOf' API r : 10029-24901-02 07/04/06 KSE/PAG OLV C/0 04/25/13 MSS.,'..M,1)F?I IF'Xfl 1[ (14/19'134 8E033,T'11'4 RI14E 1233'Rt& 142 FH. OCi/0dm ow/RK: DRGDRAFT CY}A 02/07/14 RIC Ann()*nKTORtwo) 04/3)1+08 CJKIPSV GLV CO' (O4#20108) RPExploratiaa lAtaska) • 0 m^ co N V N W C) O (O rr cov n et common mo 46 66N TO e o C 7 .Nm nN Ncommon-o N nm CU v Co aa0 N CO Ul0 U)CON U) W e-4 W mO NON 6 Ch N0 tV 0O 600 W v C)o) N r- 1 - CO 0N. r r co Co m 01 CV O W ry(Or NO V CD OU)CO my N. • 000 O O 0000 NNN C)V U)C)e� ,I.0 m CO CD OO W W W W W CO CO r CO CO W W W CO co W CO co 0 n n n n n r CO CO co CO (Cr.0 nn n n n n n n 1. nrnnr co n n nn nn n r r nn d W W W CO W CO CO W co W W CO CO 0 W W 0 CID cO cO 0 m W W W b Q C) a- 0N CO CO C) CO r co ONON)N U),-et(O O 000^co No co Q CO NC) 0 C n c W .- O O N CO CO 0(CD 00 .N m a,m N NI-CO'U N c0 O r- S P. 00 W— — N NNN.-W Tio•60r C O MB.,0 N COCV CO0 O eY 0 C000 Co Co Co Coo CO lO u) CD cmn co UW) ti cooco c m M CO N CO N q p 2 ,et- CO V V vV V V CD 01 VetettV V etQQVV CO R N mO0U ( mamma .1mmh(0Nhu)CO O U) tO0((0(0 O 0(00 t0 0f.i U) h N C0 N 0 A O 23 n c0 N rN W b mo-n r W Wnm Oen N nN m m O0 V 0 mm p C N N N M m N 6N N N NNN V of 4,.era a U)U')U)O U)co O. 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Date: 20-Jan-2015 Lat: N 70 16 4.21 Northing: 5:49574'9M Grid Conv: 1.3403' Slot 07-074 TVD Ret. Rotary Table(60.871t above MSL) MagDem 19.505° FS: 57590.527n1 Gravity FS: 1001.998mgn(9.80665 Based) Lon: W 148 34 34.22 Eastlng: 676067.2@US Scale Fact: 0.99993522 Plan:07-07C(P25) 0 1000 2000 3000 4000 5000 6000 7000 8000 0 '_Kr 0 oMD 1000 1000 2000 1338' 2000 2487 MD 10 Survey 2%1 MD Top Whipstock 2750 MD Base Whipstock • 2766 MD" SV4(2798.87 TVD) . Cry 3.5/100 3000 2786 MD 3000 Coy 3.51100 2896 MD SV3'(93418Yhflin End Cry 3500 MD 4000 F 0 1.0 71 m UG3(473iei rvbi"""' cS 50005000 11) p • 9100 6609 MD 6000 W'si(6`oiTei rvo)_._.._•._.._.._.._.._.» .._.._. ....,_.... ........... .._..-.._..-.._,.«,_ _ ,..........,_,»...... .................... ..,........»..... ...,.................... 6000 • 694f(3723Bi TT[1).._.._.._.._.._.._.._.._.._.._ Coy 9100 6442 MD 7000 7000 • End Coy 6577 MD Tgt/Sag 9477 MD bitiV]8/9i Yvo)•._.._.._.._.._.._.._.._.._.._.._.._.._. 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'• ein. ..':1.."1:.;,.750,*'ig 1i1iFU ..` .°.` 41" a c :0 T107 01 APB co an + ; h N Q' �0 • • N ./.LW., �, 6 09 o v N man.•::: • •'�a _it7; 0 .` s in co - co N O o tY OrWill'0.WIPPI • I r i cc, 4%k ,,,,. ci5 0 A . .:, eir,"Alp5/B., c:, ';. -o 0 o c c �rj ite-L,P • !S* f �+ > > ao o 6 5,f0 ��,,,rrr��'-*�I' `1 • 6 •N M O� 0_0_oa.0_ -;,,,-• -/6p''' R6Og L 2 6 �\1" to •c , 1 % 3 v 0 0 0 .0(n —0i.7) a I a 0 0 0 0 0 0 0 a a a a _ a) 0 0 0 0 0 0 0 0 0 a a 0 0_ ❑ - W d' 1' N W '' N N M (W7 1- (uij sn 008) (+)43•ioN/(-)ylnos ro 0 o_ c- 0 9o0j90 SO J!n •�� 6!LO/ LI t0/LL t� ,k,0- �� Ln co ! e1 m 9 n� I .. i9Z o c , ♦ Zti in to S4", ,' , O z8dbCe 9 M 6 —o 1-'33A ey _ J3-333APB o Jin o 0 o 0 to s c'? 0 0 `oca—Lo I o o o C N BBQ ZO�Coyo 01.01 P o 0 1 + o in' o W o op TnaN 0 CO �6 0 N .Z GQ O 07 4°' 6 d i2 d' OSS .6 9 o 6 ;0 Ill 0 Fj•�t ill ` L1. elisxii#4 ;Dt. —CD�al___- • 1 s 0 9>. o •f_m N. o D0occ 1 opAmco a_aodn. .0„0... !r. N .� o f�2�n y o o 0 0 0 0 0 0 0 0 0 0 0 0 l 0 — N Un 0 in o U) "9 o In 0 in o N 0 N N 7 N N f? (7 V (ui sn 001-) (+)q JoN/(-)4]nos en: Plan#2b 07-07C (07-07A/Plan 07-04 1366 83'6 7 1 r 44L.T �\ \\,, -_-_----,,_ � a yr �6j O \ O / q/ oo O COMPASS 5000.1 Build 61 10/21/2014 10:54 AM • S A ...A71-‘,2zi 4 28 27 ' -- illk os.? % 1t/ 28 27 - r ` 33 34- _. 33 34. AN lti . 711 814E Y/C/N/TY, fiAP__ - SGA G E: 1 = 4000' V. 1 - 0.5. 7 - - - YVELL 7A y= 5,949,574.79 I _. X = Co-6.,c. $72O -k-- GAT. 70 / ,'04.2// " __7A I LONG. 145�34'34.223# ELEYAT/ON O/ NM/ 0.5.7 COe. O " C--,'"e-e_.,4/2 . - 14/6-5 50X = 26,57 = . FAO 17ROT1?A CTE 0 SEC. 33 d 34 T 11N, R/4- U.i.f. -4av",1Y - SCA LE= 1" = 400' `� ��'O_FQC:4_S �j I HEREBY CERTIFY THAT I AM �P•.. • f �* PROPERLY REGISTERED AND1 +1 r'l g LICENSED TO PRACTICE LAND! •• SURVEYING IN THE STATE OF; �, .. .'! MAR ;� ,,. [�-; :ALASKA AND THAT THIS PLAT' 0.—,.. LOREN M- SEISE • N!.AR I- 1983 . REPRESENTS AN AS-BUILT SURVEY(j • 1%1.` ' NO. 3822_S .'Z."r MADE BY ME, AND THAT ALL4 �••, �. 4° A!aSk Cil: Ga:,Com. Commission DIMENSIONS AND OTHER DETAILS 44 tlirgrIssrciity*��` ARE CORRECT, AS OF: 2_23 53 I Of?AWA/Br: g 83 - 51-17::-= - /7_S. 7/7Q AS-St//LT OATS: ,FEB_23,/983a �� CO Alaska- -- - - - t. Ra , Inc. Ar ! S Oilfield Services,Alaska Schlumberger Drilling & Measurements Schlumberger 6411 A Street Anchorage,AK 99518 Tel (907)273-1700 Monday October 20, 2014 Brad Gorham PBU BOA DS07-07C (P2b) BP Exploration (Alaska) Inc. Doyon 14 Close Approach Analysis We have examined the potential intersections of the subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two hundred feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. 3. All depths are relative to the planned well profile. Survey Program: Please see BP survey program on the anti-collision summary Survey Interval Intermediate hole: 1 per stand— 93 ft(except where planned/actual dls is 5/100 or greater) Production hole: 1 per stand— 93 ft(except where planned/actual dls is 5/100 or greater) Close Approach Analysis results: Under method (2), note: 02-06B, 02-26/26APB1/APB2/26B/26C, and 07-07 fail the major risk rule. They pass a risk rule of 1:10 07-02B and 07-05 fail the major risk rule. They pass a risk rule of 1:20. The BP TCRW's are at the client office. Rule sets are used per the client. There is potential to see magnetic interference from the planned KOP of 2750'md to±3100'md. All data documenting these procedures is available for inspection at the Drilling & Measurements Drilling Engineering Center(DEC). Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder plot will be provided. Checked by: Scott DeLapp 10/20/2014 S N • N _ M Q - - _ ' - U) n - Co -- o U) _ N _ -- o 0 _ Co -- N n _ -- O If) O co -- In C O - O v L O _ co Q. a) - 0 W n - N N O 4 p O O D G - N N 0) _ N - W - N -- 17 1` O _ N U - o v7 Ca• 0 - N O _�Q O -co cz co - to D C C N dCOd - N • )= N C _ - u7 n r N O I I I I I I I I I I I I I 1111 1111 1111 1111 1 1 1 1 I I I ! 1111 1 1 1 1 1 1 1 1111 1111 r- 0 O 4] O In O 117 O Ill O In O 1- (0 (0 N In M M CU CU (ui/ sn os.) uoiwi das aqua° aJluao 0 I BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-07A Project: Prudhoe Bay TVD Reference: 07-07C @ 60.87usft(014 plan) Reference Site: PB DS 07 MD Reference: 07-07C©60.87usft(D14 plan) Site Error: 0.00usft North Reference: True Reference Well: 07-07A Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 07-07C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#2b 07-07C Offset TVD Reference: Offset Datum Reference Plan#2b 07-07C Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 5.00usft Error Model: ISCWSA Depth Range: 2,690.87 to 14,115.52usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,608.12usft Error Surface: Elliptical Conic Survey Tool Program Date 10/21/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 90.87 2,690.87 07-07A Srvy 2 GYD-GC-MS(07-07A) GYD-GC-MS Gyrodata gyrocompassing m/s 2,690.87 2,750.00 Plan#2b 07-07C(Plan 07-07C) GYD-GC-MS Gyrodata gyrocompassing m/s 2,750.00 3,100.00 Plan#2b 07-07C(Plan 07-07C) INC+TREND Inclinometer+known azi trend 3,100.00 4,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 4,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 4,600.00 5,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard i 3,100.00 5,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,100.00 5,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard I 3,100.00 5,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,600.00 6,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 6,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 6,100.00 6,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 6,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 6,600.00 7,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 7,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 7,100.00 7,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 7,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 7,600.00 8,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 8,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,100.00 8,600.00 Plan#2b 07-07C(Plan 07-07C) MIND MWD-Standard 3,100.00 8,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,600.00 9,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MIND-Standard 3,100.00 9,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,100.00 9,480.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 9,480.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,480.00 11,000.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 11,000.00 Plan#2b 07-07C(Plan 07-07C) MVVD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 11,000.00 11,500.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 11,500.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 11,500.00 12,000.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 12,000.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 12,000.00 12,500.00 Plan#2b 07-07C(Plan 07-07C) MWD MIND-Standard 9,480.00 12,500.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MIND+IFR+Multi Station W/O Crustal 12,500.00 13,000.00 Plan#2b 07-07C(Plan 07-07C) MIND MIND-Standard 9,480.00 13,000.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 13,000.00 13,500.00 Plan#2b 07-07C(Plan 07-07C) MIND MIND-Standard 1 9,480.00 13,500.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 13,500.00 14,115.52 Plan#2b 07-07C(Plan 07-07C) MIND MWD-Standard 9,480.00 14,115.52 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 10/22/2014 12:01:08PM Page 2 of 5 COMPASS 5000.1 Build 61 0 • BP Anticolljsion Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-07A Project: Prudhoe Bay TVD Reference: 07-07C @ 60.87usft(D14 plan) Reference Site: PB DS 07 MD Reference: 07-07C @ 60.87usft(D14 plan) Site Error: O.Oousft North Reference: True Reference Well: 07-07A Survey Calculation Method: Minimum Curvature Well Error: O.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 07-07C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#2b 07-07C Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 02 02-06-02-06-02-06 13,568.98 11,705.00 568.22 243.34 327.24 Pass-Major Risk 02-06-02-06A-02-06A 12,918.66 12,307.00 463.15 273.31 189.67 Pass-Major Risk 02-06-02-06B-02-06B 13,601.19 12,100.00 61.41 14.80 58.33 Pass-Minor 1/10 02-06-02-06C-02-06C 13,608.67 11,470.00 773.93 246.40 528.68 Pass-Major Risk 02-26-02-26-02-26 11,871.18 11,160.00 530.92 11.04 530.37 Pass-Minor 1/10 02-26-02-26A-02-26A 11,924.64 10,925.00 597.76 2.38 596.49 Pass-Minor 1/10 02-26-02-26APB1-02-26APB1 11,906.74 10,955.00 593.29 2.53 591.87 Pass-Minor 1/10 02-26-02-26APB2-02-26APB2 11,898.56 10,970.00 592.47 2.54 591.04 Pass-Minor 1/10 02-26-02-2613-02-26B 11,890.23 10,755.00 1,088.99 2.54 1,087.14 Pass-Minor 1/10 02-26-02-26C-02-26C 10,209.74 12,890.00 142.45 11.85 133.60 Pass-Minor 1/10 PB DS 07 07-02-07-02-07-02 4,512.48 4,435.00 442.33 171.27 287.48 Pass-Major Risk 07-02-07-02A-07-02A 12,586.06 12,075.00 478.59 298.38 188.67 Pass-Major Risk 07-02-07-02B-07-02B 10,296.14 11,915.00 215.21 3.72 214.76 Pass-Minor 1/20 07-03-07-03-07-03 3,176.26 3,165.00 511.01 146.67 364.27 Pass-Major Risk 07-03-07-03A-07-03A 3,177.10 3,160.00 511.18 146.84 364.28 Pass-Major Risk 07-03-07-03APB1-07-03APB1 3,177.10 3,160.00 511.18 146.84 364.28 Pass-Major Risk 07 04 07 04 07 04 3,261.46 3,240.00 363.67 184.34 179.30 Pass-Major Risk 07-04-07-04A-07-04A 3,261.46 3,240.00 363.67 184.34 179.30 Pass-Major Risk 07-05-07-05-07-05 3,945.27 3,950.00 100.92 1.98 99.21 Pass-Minor 1/20 07 06 07 06 07 06 3,135.56 3,140.00 149.47 145.37 9.47 Pass-Major Risk 07-06-07-06A-07-06A 3,135.56 3,140.00 149.47 145.37 9.47 Pass-Major Risk 07-06-07-06B-07-0613 3,134.64 3,130.00 149.36 145.19 9.47 Pass-Major Risk 07-07-07-07-07-07 2,692.65 2,695.00 12.79 4.95 7.84 Pass-Minor 1/10 07-07A-07-07A-07-07A 3,101.14 3,115.00 47.70 96.01 -46.96 FAIL-Major Risk 07-07A-07-0713-07-0713 3,101.14 3,115.00 47.70 96.12 -47.07 FAIL-Major Risk 07-08-07-08-07-08 2,944.40 2,960.00 106.81 79.85 35.90 Pass-Major Risk 07-08-07-08A-07-08A 2,944.40 2,960.00 106.81 79.85 35.90 Pass-Major Risk 07-08-07-08B-07-0813 2,943.18 2,950.00 106.61 79.51 35.90 Pass-Major Risk 07-09-07-09-07-09 2,961.79 2,990.00 227.71 82.45 150.46 Pass-Major Risk 07-09-07-09A-07-09A 2,961.79 2,990.00 227.71 82.45 150.46 Pass-Major Risk 07-10-07-10-07-10 3,100.00 3,155.00 370.17 126.58 258.02 Pass-Major Risk 07-10-07-10A-07-10A 3,100.00 3,155.00 370.17 126.58 258.02 Pass-Major Risk 07 11 07 11 07 11 3,100.00 3,170.00 499.65 142.24 369.80 Pass-Major Risk 07-11-07-11A-07-11A 3,100.00 3,170.00 499.65 142.24 369.80 Pass-Major Risk 07-15-07-15-07-15 4,164.36 4,015.00 370.80 181.38 190.82 Pass-Major Risk 07-15-07-15A-07-15A 4,164.36 4,015.00 370.80 181.38 190.82 Pass-Major Risk 07-16-07-16-07-16 3,853.88 3,625.00 502.29 158.25 365.97 Pass-Major Risk 07-16-07-16A-07-16A 3,853.88 3,625.00 502.29 158.25 365.97 Pass-Major Risk 07-17-07-17-07-17 4,126.75 3.820.00 568.53 182.56 431.78 Pass-Major Risk 07 18 07 18 07 18 7,427.90 7,085.00 387.45 345.87 42.87 Pass-Major Risk 07-19-07-19-07-19 2,695.82 2,640.00 1,010.66 59.49 958.39 Pass-Major Risk 07-19-07-19A-07-19A 2,695.82 2,640.00 1,010.66 59.49 958.39 Pass-Major Risk 07-20-07-20-07-20 4,110.47 3,730.00 638.90 176.21 516.05 Pass-Major Risk 07-20-07-20A-07-20A 4,110.47 3,730.00 638.90 176.21 516.05 Pass-Major Risk 07-20-07-2013-07-2013 4,110.47 3,730.00 638.90 176.21 516.05 Pass-Major Risk 07-21-07-21-07-21 4,597.53 4,365.00 290.25 164.09 126.14 Pass-Major Risk 07-22-07-22-07-22 3,915.41 3,580.00 783.12 163.77 634.16 Pass-Major Risk 07-22-07-22A-07-22A 3,915.41 3,580.00 783.12 163.77 634.16 Pass-Major Risk 07-25-07-25-07-25 2,690.87 2,715.00 468.02 39.44 428.72 Pass-Major Risk 07-25-07-25A-07-25A 2,690.87 2,715.00 468.02 39.44 428.72 Pass-Major Risk 07-26-07-26-07-26 2,693.79 2,715.00 364.76 43.31 321.53 Pass-Major Risk 10/22/2014 12:01:08PM Page 3 of 5 COMPASS 5000.1 Build 61 I 0 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-07A Project: Prudhoe Bay TVD Reference: 07-07C @ 60.87usft(D14 plan) Reference Site: PB DS 07 MD Reference: 07-07C @ 60.87usft(014 plan) Site Error: 0.00usft North Reference: True Reference Well: 07-07A Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 07-07C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#2b 07-07C Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 07 07-27-07-27-07-27 3,592.03 3,410.00 627.12 156.53 481.05 Pass-Major Risk 07-32-07-32-07-32 3,116.52 3,165.00 432.46 131.24 306.53 Pass-Major Risk 07-32-07-32A-07-32A 3,116.52 3,165.00 432.46 131.24 306.53 Pass-Major Risk 07-32-07-32APB1-07-32APB1 3,116.52 3,165.00 432.46 131.24 306.53 Pass-Major Risk 07-32-07-326-07-326 3,116.52 3,165.00 432.46 131.07 306.71 Pass-Major Risk 07-32-07-32PB1-07-32PB1 3,116.52 3,165.00 432.46 131.23 306.54 Pass-Major Risk 07-33-07-33-07-33 2,711.67 2,690.00 1,244.57 56.64 1,190.05 Pass-Major Risk 07-33-07-33A-07-33A 2,711.67 2,690.00 1,244.57 56.79 1,189.89 Pass-Major Risk 07-33-07-33APB1-07-33APB1 2,711.67 2,690.00 1,244.57 56.64 1,190.05 Pass-Major Risk 07-33-07-33APB2-07-33APB2 2,711.67 2,690.00 1,244.57 56.64 1,190.05 Pass-Major Risk 07-33-07-336-07-33B 2,711.67 2,690.00 1,244.57 56.79 1,189.89 Pass-Major Risk 07-34-07-34-07-34 2,709.44 2,670.00 1,201.54 54.33 1,148.97 Pass-Major Risk 07-34-07-34A-07-34A 2,709.44 2,670.00 1,201.54 54.33 1,148.97 Pass-Major Risk 07-34-Plan 07-34B-Plan#2 07-34B 7,626.37 7,455.00 446.10 349.10 100.34 Pass-Major Risk 07-35-07-35-07-35 5,000.30 4,720.00 263.65 156.34 107.36 Pass-Major Risk 07-35-07-35A-07-35A 5,000.30 4,720.00 263.65 156.18 107.52 Pass-Major Risk 07-36-07-36-07-36 4,595.49 4,050.00 1,524.27 203.91 1,422.73 Pass-Major Risk 07-37-07-37-07-37 3,345.78 3,355.00 761.42 160.97 600.97 Pass-Major Risk 10/22/2014 12:01:08PM Page 4 of 5 COMPASS 5000.1 Build 61 ` �� I pm�o : Pmdhoe S�o� P8 DS 07 �� Well: 07-07A Wellbore: Plan 07-07C From Colour mmD Design: Plan #2 07-07C 0 2400 2400 urmo From 245O'md(3UO'mdabove planned KOP)1n95OO'md ( ') uron uonn o Scan intoro| 25 ft 0 9000 9500 10000 11000 12000 I( \3.0 I\.%4 i 4 , ////e/.e.v.r,.."1,., iiii--sN i ,,/44 #10( /4' I i V ------4-... ----/.. •--: • ' ..•• ' 12000 -- - - 13000 i </1:"// 'f` )i \kx --l'-------------/------"-•- ..' "••••• -.•-• ..s-,. -. 13000 f\ 4:,Foil 004010144,1 /je,b7/,,/fiet,,,„ A , ,....., --___....... -...._.. .-:,:._, ,..... .....• -..... 14200 Air,,ii.t4,,,. ..1-4f 1,01/:,11/11111 ‘liciiiiiii i \) -::::- . '" ' ''.--:::::',.:::::-<'• ' '-':...2...••-•; •„ '. so 14,10$:$21.‘itgrt\-‘8iitliii - 9 -'1.11-1-1-1::::::/:::::..--- --2/.-::::::::::::::::::::::-.:,:\s"ii:.::::::::-:..._ wttat-titiolo\l,\ \\\\\.-7,,s\t,\IitioN.ifili ........,..:::,.. / .----::-.:,..":::::::::::.:::...........>:::::.::::::::::-.s...:::..„:::::::•:::::::,::-..:..\:„.',.... Scale 1 inch :50ft 3000 - ' 4000 Several wells fail the major risk 4000 -- - 5000 00 Wells pass risk rules 5000 __ 6000 See AC summary report for details 6000 7000 - ' ''t fi:At;iiii411\4%*,41::i-..:- ,A:-- - ----...---, . •.-. ',. '... 2:,:.-k., \ '.. .. \ ' it k 1 ' 1, 1 1, it 41111*4NPAekttilitifti;i;.;#1: - 1'31°K ..1.1:1'.....r:i.'.1:-...• ..\:.."11.:-..::::':„.::':''''... \\,.\\ .., \-, ..- . ' 4. »»um eipritoSe.,00,4400111000,t1;stitielIVIMAVAA.NPriZz-t•ZFSFI.`,, ,---_-_..;-:.'Zi...-"TeAraraxst,i1;aririgL_ birawrtirikiraPari41,447414,411414.i 4.400.0dtgio,v„,, ,,,,r,:leter-4-,4*43-,..-1.-..,v_t etto,,, f#4 4sviAt os,4#4\ 4,,v,TA 0.4,A'itaii4.;:h,fire,go t...,A.,„;:,,..,,,,r,,,,, .t.....,, _4, AA* , , • \*iik i 8 Azimuth from North [1 vs Centre to Centre Separation [41 usftlin] ProjSect:ite: PPrBudDS hoe07 Bay • Well: 07-07A Wellbore: Plan 07-07C Design: Plan#2b 07-07C From Colour To MD From 9400'md (7")to TD 0 2400 Scan interal 25 ft 2400 2750 Scale 1 inch :50ft 2750 3000 Several wells fail the major risk 3000 4000 Wells pass risk base rules See AC summary report for details 4000 5000 oti 5000 6000 ti� 0 6000 -- — 7000 ti - ' 7000 — 8000 10182#02010222.__ --•- i 40244.- 8000 9000 9000 9500 330. _ 0 ------------- , 9500 10000 --., -,- 10000 11000 11000 12000 12000 13000 100--- 13000 14200 75 •;-1593 •' '•,13594 i 1369; 270 i . • 8::: 06 240 .J,., :.*.•'' 120 J< - -1ssr5" 13518 0 125 210 0cli 150 136t9 :._ -------- ------ --- - ------- 150 180 Azimuth from North El vs Centre to Centre Separation [40 usft/in] • North America - ALASKA - BP Prudhoe Bay PB DS 07 07-07A Plan 07-07C Plan #2b 07-07C Anticollision Summary Report 09 February, 2015 • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-07A Project Prudhoe Bay TVD Reference: 07-07C @ 60.87usft(D14 plan) Reference Site: PB DS 07 MD Reference: 07-07C©60.87usft(D14 plan) Site Error. 0.00usft North Reference: True Reference Well: 07-07A Survey Calculation Method: Minimum Curvature Well Error. 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 07-070 Datalase: r^EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#2b 07-07C Offset TVD Reference: Offset Datum Reference Plan#2b 07-07C Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 5.00usft Error Model: ISCWSA Depth Range: 2,690.87 to 14,115.52usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,608.12usft Error Surface: Elliptical Conic Survey Toot Program Date 10/21/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 1 90.87 2,690.87 07-07A Srvy 2 GYD-GC-MS(07-07A) GYD-GC-MS Gyrodata gyrocompassing m/s 2,690.87 2,750.00 Plan#2b 07-07C(Plan 07-07C) GYD-GC-MS Gyrodata gyrocompassing m/s 2,750.00 3,100.00 Plan#2b 07-07C(Plan 07-07C) INC+TREND Inclinometer+known azi trend 3,100.00 4,600.00 Plan#2b 07-070(Plan 07-07C) MWD MWD-Standard 3,100.00 4,600.00 Plan#2b 07-070(Plan 07-070) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 4,600.00 5,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 5,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,100.00 5,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 5,600.00 Plan#2b 07-070(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,600.00 6,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 6,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 6,100.00 6,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 6,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 6,600.00 7,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 7,100.00 Plan#2b 07-070(Plan 07-070) MVVD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 7,100.00 7,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 7,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 7,600.00 8,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard ' 3,100.00 8,100.00 Plan#2b 07-070(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,100.00 8,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 8,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,600.00 9,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 9,100.00 Plan#2b 07-070(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,100.00 9,480.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 9,480.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,480.00 11,000.00 Plan#2b 07-070(Plan 07-07C) MWD MWD-Standard 9,480.00 11,000.00 Plan#2b 07-070(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 11,000.00 11,500.00 Plan#2b 07-070(Plan 07-07C) MWD MWD-Standard 1 9,480.00 11,500.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 11,500.00 12,000.00 Plan#2b 07-07C(Plan 07-070) MWD MWD-Standard 9,480.00 12,000.00 Plan#2b 07-070(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal I 12,000.00 12,500.00 Plan#2b 07-070(Plan 07-07C) MWD MWD-Standard 9,480.00 12,500.00 Plan#2b 07-070(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 12,500.00 13,000.00 Plan#2b 07-070(Plan 07-07C) MWD MWD-Standard 9,480.00 13,000.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 13,000.00 13,500.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 13,500.00 Plan#2b 07-070(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 13,500.00 14,115.52 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 14,115.52 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 2/9/2015 9:15:21AM Page 2 of 5 COMPASS 5000.1 Build 61 • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-07A Project: Prudhoe Bay TVD Reference: 07-07C @ 60.87usft(D14 plan) Reference Site: PB DS 07 MD Reference: 07-07C @ 60.87usft(D14 plan) Site Error: 0.00usft North Reference: True Reference Well: 07-07A Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 07-07C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#2b 07-07C Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 02 02-06-02-06-02-06 13,568.98 11,705.00 568.22 243.34 327.24 Pass-Major Risk 02-06-02-06A-02-06A 12,918.66 12,307.00 463.15 273.31 189.67 Pass-Major Risk 02-06-02-06B-02-06B 13,595.38 12,045.00 92.29 247.79 -106.70 FAIL-Major Risk 02-06-02-06C-02-06C 13,608.67 11,470.00 773.93 246.40 528.68 Pass-Major Risk 02-26-02-26-02-26 11,876.59 11,140.00 531.27 934.51 -400.63 FAIL-Major Risk 02-26-02-26A-02-26A 11,911.61 10,970.00 604.98 920.18 -290.64 FAIL-Major Risk 02-26-02-26AP61-02-26APB 1 11,879.51 11,010.00 598.97 919.94 -305.70 FAIL-Major Risk 02-26-02-26APB2-02-26APB2 11,869.37 11,015.00 596.34 919.84 -308.02 FAIL-Major Risk 02-26-02-26B-02-26B 11,871.61 10,810.00 1,093.36 792.58 325.75 Pass-Major Risk 02-26-02-26C-02-26C 10,226.70 12,870.00 143.83 835.72 -687.27 FAIL-Major Risk PB DS 07 07-02-07-02-07-02 4,512.48 4,435.00 442.33 171.27 287.48 Pass-Major Risk 07-02-07-02A-07-02A 12,586.06 12,075.00 478.59 298.38 188.67 Pass-Major Risk 07-02-07-02B-07-02B 10,291.25 11,920.00 215.21 276.37 -57.85 FAIL-Major Risk 07-03-07-03-07-03 3,176.26 3,165.00 511.01 146.67 364.27 Pass-Major Risk 07-03-07-03A-07-03A 3,177.10 3,160.00 511.18 146.84 364.28 Pass-Major Risk 07-03-07-03APB1-07-03APB1 3,177.10 3,160.00 511.18 146.84 364.28 Pass-Major Risk 07-04-07-04-07-04 3,261.46 3,240.00 363.67 184.34 179.30 Pass-Major Risk 07-04-07-04A-07-04A 3,261.46 3,240.00 363.67 184.34 179.30 Pass-Major Risk 107-05-07-05-07-05 3,554.68 3,555.00 158,28 151.97 15.47 Pass-Maior Risk I 07-06-07-06-07-06 3,135.56 3,140.00 149.47 145.37 9.47 Pass-Major Risk 07-06-07-06A-07-06A 3,135.56 3,140.00 149.47 145.37 9.47 Pass-Major Risk 07-06-07-066-07-06B 3,134.64 3,130.00 149.36 145.19 9.47 Pass-Major Risk 07-07-07-07-07-07 2,831.71 2,835.00 19.96 62.59 -36.85 FAIL-Major Risk 07-07A-07-07A-07-07A 3,101.14 3,115.00 47.70 96.01 -46.96 FAIL-Major Risk 07-07A-07-076-07-07B 3,101.14 3,115.00 47.70 96.12 -47.07 FAIL-Major Risk 07-08-07-08-07-08 2,944.40 2,960.00 106.81 79.85 35.90 Pass-Major Risk 07-08-07-08A-07-08A 2,944.40 2,960.00 106.81 79.85 35.90 Pass-Major Risk 07-08-07-08B-07-086 2,943.18 2,950.00 106.61 79.51 35.90 Pass-Major Risk 07-09-07-09-07-09 2,961.79 2,990.00 227.71 82.45 150.46 Pass-Major Risk 07-09-07-09A-07-09A 2,961.79 2,990.00 227.71 82.45 150.46 Pass-Major Risk 07-10-07-10-07-10 3,100.00 3,155.00 370.17 126.58 258.02 Pass-Major Risk 07-10-07-10A-07-10A 3,100.00 3,155.00 370.17 126.58 258.02 Pass-Major Risk 07-11-07-11-07-11 3,100.00 3,170.00 499.65 142.24 369.80 Pass-Major Risk 07-11-07-11A-07-11A 3,100.00 3,170.00 499.65 142.24 369.80 Pass-Major Risk 07-15-07-15-07-15 4,164.36 4,015.00 370.80 181.38 190.82 Pass-Major Risk 07-15-07-15A-07-15A 4,164.36 4,015.00 370.80 181.38 190.82 Pass-Major Risk 07-16-07-16-07-16 3,853.88 3,625.00 502.29 158.25 365.97 Pass-Major Risk 07-16-07-16A-07-16A 3,853.88 3,625.00 502.29 158.25 365.97 Pass-Major Risk 07-17-07-17-07-17 4,126.75 3,820.00 568.53 182.56 431.78 Pass-Major Risk 07-18-07-18-07-18 7,427.90 7,085.00 387.45 345.98 42.76 Pass-Major Risk 07-19-07-19-07-19 2,695.82 2,640.00 1,010.66 59.49 958.39 Pass-Major Risk 07-19-07-19A-07-19A 2,695.82 2,640.00 1,010.66 59.49 958.39 Pass-Major Risk 07-20-07-20-07-20 4,110.47 3,730.00 638.90 176.21 516.05 Pass-Major Risk 07-20-07-20A-07-20A 4,110.47 3,730.00 638.90 176.21 516.05 Pass-Major Risk 07-20-07-206-07-206 4,110.47 3,730.00 638.90 176.21 516.05 Pass-Major Risk 07-21-07-21-07-21 4,597.53 4,365.00 290.25 164.09 126.14 Pass-Major Risk 07-22-07-22-07-22 3,915.41 3,580.00 783.12 163.77 634.16 Pass-Major Risk 07-22-07-22A-07-22A 3,915.41 3,580.00 783.12 163.77 634.16 Pass-Major Risk 07-25-07-25-07-25 2,690.87 2,715.00 468.02 39.44 428.72 Pass-Major Risk 07-25-07-25A-07-25A 2,690.87 2,715.00 468.02 39.44 428.72 Pass-Major Risk 07-26-07-26-07-26 2,693.79 2,715.00 364.76 43.31 321.53 Pass-Major Risk 2/9/2015 9:15:21AM Page 3 of 5 COMPASS 5000.1 Build 61 0 • BP Anticollision Report Company: North America-ALASKA-BP Local'Co-ordinate Reference:, Well 07-07A Project: Prudhoe Bay TVD Reference: 07-07C @ 60.87usft(D14 plan) Reference Site: PB DS 07 MD Reference: 07-07C @ 60.87usft(D14 plan) Site Error: 0.00usft North Reference: True Reference Well: 07-07A SurveyCalculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 07-07C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#2b 07-07C Offset TVD Reference: Offset Datum Summary Reference Offset Centre to ko-Do Allowable Measured Measured Centre Distance Deviation '/,:..,zor Warning Site Name Depth Depth Distance (ugh) from Plan Offset Well Wellbore-Design (usft) (usC) (usft) (usft) PB DS 07 07-27-07-27-07-27 3,592.03 3,410.00 627.12 156.53 481.05 Pass-Major Risk 07-32-07-32-07-32 3,116.52 3,165.00 432.46 131.24 306.53 Pass-Major Risk 07-32-07-32A-07-32A 3,116.52 3,165.00 432.46 131.24 306.53 Pass-Major Risk 07-32-07-32APB1-07-32APB1 3,116.52 3,165.00 432.46 131.24 306.53 Pass-Major Risk 07-32-07-32B-07-32B 3,116.52 3,165.00 432.46 131.07 306.71 Pass-Major Risk 07-32-07-32PB1-07-32PB1 3,116.52 3,165.00 432.46 131.23 306.54 Pass-Major Risk 07-33-07-33-07-33 2,711.67 2,690.00 1,244.57 56.79 1,189.90 Pass-Major Risk 07-33-07-33A-07-33A 2,711.67 2,690.00 1,244.57 56.79 1,189.90 Pass-Major Risk 07-33-07-33APB1-07-33APB1 2,711.67 2,690.00 1,244.57 56.79 1,189.90 Pass-Major Risk 07-33-07-33APB2-07-33APB2 2,711.67 2,690.00 1,244.57 56.79 1,189.90 Pass-Major Risk 07-33-07-33B-07-33B 2,711.67 2,690.00 1,244.57 56.79 1,189.90 Pass-Major Risk 07-34-07-34-07-34 2,709.44 2,670.00 1,201.54 54.33 1,148.97 Pass-Major Risk 07-34-07-34A-07-34A 2,709.44 2,670.00 1,201.54 54.33 1,148.97 Pass-Major Risk 07-34-Plan 07-34B-Plan#3 07-34B 7,626.02 7,455.00 446.08 349.04 100.39 Pass-Major Risk 07-35-07-35-07-35 5,000.30 4,720.00 263.65 156.34 107.36 Pass-Major Risk 07-35-07-35A-07-35A 5,000.30 4,720.00 263.65 156.18 107.52 Pass-Major Risk 07-36-07-36-07-36 4,595.49 4,050.00 1,524.27 203.91 1,422.73 Pass-Major Risk 07-37-07-37-07-37 3,345.78 3,355.00 761.42 160.97 600.97 Pass-Major Risk Plan 07-38-Plan 07-38-Plan#3 07-38 3,646.49 3,480.00 600.17 156.53 464.98 Pass-Major Risk 2/9/2015 9:15:21AM Page 4 of 5 COMPASS 5000.1 Build 61 • • ol i: = m tjIi w a me w ¢ < w a O Z 2 Z ci y. m Y U@ m O < Z ' 01 P.1 ititet Z 1 czco— q 111 AI n 0 w Z 1 L. Z n O _ 411,411, -IRENINI.� a e. g 5W 11 al 1 i w • - q . .fel 4 El kgkg. 3g1:- 1!1 _ I r 1 =n 1 111 i',... H' v v.) GNI 1111 *pi won < 5 s 1.1 o T Lb! r '*.b ; i " 1 * �: "* 1 1 .ice 'iA-I ft ' - Clik i i �ii�_ I n i 1 S, i i 1 •r ' • • STAGE 25 TUBING BONNET 11 Il, 11111 MIE (Item D1 ,A111111111111ft DING GASKET 1 (Item 012, 171448) F -Ifs ---- CONTROL LINE PLUG t *' --- L- -- CONTROL LINE NIPPLE • , 0 ® p ' , F. ; _ _._� CONTROL LINE 1 1 UM t f Hf ,s I 7. w i 4 QC.0 Iiill 1 ill __Ilip , .- ----20" CASING , --13-3/8" CASING 9-5/8" CASING 5-1/2" TUBING • • et- CAMERON 38 44 BPXA EOA Well DS 07-07 Est Existing Equipment -I ! o / 9 4 7-1/16" 5,000*-- l of tc - 121151'. " = ri _ Eat 1 z :.....,....4.., Wit+ �' 'ipe 7_1f16 5.440 t g(( • 1. ., I I 6 i4 67 50" n L' .i) I WiliirQ-40iry-6 1 V. 7-1/16" 500011' ' s 1r ,� STT' 1 r _ _� ___1.. A so r„ --_ 1 ------4 24.5" ir , �� ) i?(�` o - j 11 3-1/8"5000 } I 1 4 3-118"5000 I• etCAMERON2?:1 ,,„ , , 11°BPXA EOA Well DS 07-07 ';' :1— '----.4 Replacement Equipment I ! I 4-e\ 4,/'.--•"' s. 4 t/to" 5.0001- ( ir4 ; 938 7:Pi 1 i , • ft '' , -. 4--I-16- 5,000# ' i ( '7i \ V * O je i '''''''' ; / '7 a 50 75 -r-----r Est I 1 4 111,W 5,000#-- ; 16.0" irri I —Flit/i. I a r A ;i _________ t 2-73-, an 26.3" Tiwtc \) 2-1/16"5000 V 1 '.\•.,__:_..: 1 .it--_-------- ' . y, t 3-1/8"5000 -f : 1-1J 110 • TRANSMITTAL LETTER CHECKLIST WELL NAME: fi.4'/;(1 e,)7--07C PTD: 21`7" Development Servicep Exploratory —Stratigraphic Test —Non-Conventional — p — FIELD: _ �_ �' POOL: 4- �P- / Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name)in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(dX2XB) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. 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O c r cc,:,), w N NR UO ON® M O 0 OIl) o O) O Orn H^ N c M N f 0 1' o E J-- N E d O O O •c C ° •a. o o I- vala a o w ri 0 a co • Pry .214 —/7- Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, December 17, 2014 1:57 PM To: 'Gorham, Bradley M' Cc: Lastufka,Joseph N Subject: RE:07-07C (PTD 214-175) Possible Revision Follow Up Flag: Follow up Flag Status: Flagged Brad, Please have a revised PTD ready for submission if you decide to move to PBU 07-07C on 12/29/14. Enough has changed to warrant a revision. We will expedite the processing so there will be no delay. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepi ialaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov From: Gorham, Bradley M [mailto:Bradley.Gorhaml bp.com] Sent: Wednesday, December 17, 2014 12:33 PM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: 07-07C Update Victoria, I just wanted to keep you in the loop for a possible change of scope on 07-07C.07-07C was originally scheduled to spud at the end of April. However,there is potential that it will get moved up on the schedule,to the first week of January, due to some permitting delays with P1-122i. If 07-07C moves up on the schedule,we would be unable to complete the well as originally planned due to necessary wellhead equipment that is—10 weeks out.The original plan,which was submitted in the approved PTD, was to cut and pull the 9-5/8" casing at"'2,300' and then run a 7" long string. However, in order to run the 7" long string in the current wellhead we need specific slips that are—10 weeks out. In light of this the new plan, assuming 07-07C moves up on the schedule,would be to cut and pull the 9-5/8" casing and then tie-back the 9-5/8" casing and cement it back to surface followed by a 7" liner. i • I We will know for sure on the 29th of December whether or not we will be able to proceed with P1-122i well or if we will in fact be moving to 07-07C. If there is anything we need to complete due to the change of scope on 07-07C please let me know.As I stated before,we just wanted to keep you up to date with our operations and the potential change. If 07- 07C does not move up on the schedule,we will go back to the original plan of running the 7" long string. I have attached a schematic of the old proposed completion and one of the new proposal. I have also attached the approved PTD. It is important to note that the depths on the schematic vary slightly.This is due to the fact the original well plan was designed for Doyon 14 and the new plan was designed for Parker 272,the plans are identical and are only different due to the difference in RKB between the two rigs. Let me know if you have any questions or require any further information. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)250-3209 Bradley.Gorham@bp.com 2 0 • ��\ 11/7 ��, THE STA 'E .�,� � 1, ass c] , , _4 333 ✓Jeri 3€ ve ire Averse "-' GOVLRNOR SF. A �T FARNF L Anchorage, Alaska 99501 3572 '` Mom- 997 279. 433 Ken Allen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-07C BP Exploration(Alaska), Inc. Permit No: 214-175 Surface Location: 1347' FNL, 138' FEL, SEC. 33, Ti 1N, R14E,UM Bottomhole Location: 4283' FNL, 1709' FWL, SEC. 35, Ti 1N, R14E, UM Dear Mr. Allen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 1 9--7_/.."7"—7'7—----- —--7 Daniel T. Seamount, Jr. Commissioner DATED this I day of November, 2014. STATE OF ALASKA RECEIVED ALA•IL AND GAS CONSERVATION COMMODN OCT 2 7 2014 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Type of work: 1 b.Proposed Well Class:.®Development Oil 0 Service-Winj •®Single Zone 1 c.Specify if well is proposed for: ❑Drill 0 Lateral 0 Stratigraphic Test 0 Development Gas 0 Service-Supply ❑Multiple Zone 0 Coalbed Gas 0 Gas Hydrates ®Redrill 0 Reentry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 2.Operator Name: 5.Bond • ®Blanket ❑Single Well 11.Well Name and Number: BP Exploration(Alaska) Inc. Bond No 6194193 • PBU 07-07C ' 3. Address 6.Proposed Depth: 12.Field/Pool(s) P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 14115' • TVD 8941' • Prudhoe Bay/Prudhoe Bay . 4a.Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: ADL 028309&028308 • 1347'FNL, 138'FEL, Sec.33,T11N, R14E, UM Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2201'FNL, 3287'FWL, Sec.34,T11N, R14E, UM December 31,2014 Total Depth 9.Acres in Property: 14.Distance to Nearest Property: 4283'FNL, 1709'FWL, Sec.35,T11N, R14E, UM 2560 25230' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 60.87' • feet 15.Distance to Nearest Well Open Surface: x 676067 • y-5949575 ' Zone- ASP4 GL Elevation above MSL: 26.57' • feet to Same Pool: 200' 16.Deviated Wells: Kickoff Depth: 2750' ' feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 119 degrees Downhole: 3321 Surface: 2426 • 18. Casing Program Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8-1/2" 7" 26# L-80 VamTop HC 9482' Surface Surface 9482' 8479' 794 sx LiteCrete, 85 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 VamTop 5165' 8950' 8009' 14115' 8941' 420 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 12870' 9054' 9584' 12760' 9040' None Casing Length Size Cement Volume MD ND Conductor/Structural 80' 20" 470 S Arcticset II 80' 80' Surface 2496' 13-3/8" 1600 sx Fondu,400 sx Permafrost'C' 2496' 2495' Intermediate 9923' 9-5/8" 500 sx Class'G', 50 Bbls Permafrost'C' 9923' 8345' Production Liner 888' 7" 400 sx Class'G' 9621'- 10509' 8143'-8773' Liner 3232' 3-1/2"x 3-3/16"x 2-7/8" 165 sx Class'G' 9565'- 12797' 8104'-9043' Perforation Depth MD(ft): 11120'- 12756' Perforation Depth ND(ft): 9016'-9040' 20.Attachments: ®Property Plat ®BOP Sketch ® Drilling Program ❑Time vs Depth Plot ❑Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct: Contact Brad Gorham,564-4649 Printed Name Ken Allen Title Engineering Team Leader EmaillBradley.Gorham©bp.com Signature /' C 3 C----------,_ Phone 564-4366 Date /O �_y/ /ti ✓ Commission Use Only ( (( Permit To Drill .- / Permit Approval Qat 4 See cover letter for Number: /../L! 7', API Number: 50-029-20901-02-00 I11I III 1 other requirements: Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas Li. contained shales: Other: 00p t -5 71-- fo 3 5-(20 p5, Samples Req'd: Oyes ["No Mud Log Req'd: Oyes Ly No A J.---tv�v 1 a r 1-7-51- to 2 5-0 c>1)5 , HZS Measures: I 1 Yes aNo Directional Survey Req'd: Yes ❑No Spacing exception req'd: ElYes No inclination-only svy Req'd: 0 Yes ITrNo APPROVED BY l APPROVED BY 4P ,'IF- COMMISSIONER THE COMMISSION Date / ( 41 Form 10-401 Revised 10/2012 Th t r r 4 o the from the date of approval(20 AAC 25.005(g Submit Formd Attachments In Duplicate �` <<3//4 f 'fi a W14 '••20 ;4)- 'C4 1110 11) 44. .004 To: Alaska Oil & Gas Conservation Commission From: Brad Gorham, ODE Date: October 24, 2014 Re: 07-07C Permit to Drill The planned 07-07C well is currently scheduled to be drilled by Doyon 14 in December 2014. The rotary sidetrack is a horizontal Ivishak producer. 07-07B will be abandoned and jet cut pre-rig. The 5-1/2" tubing will then be pulled with the rig. An EZSV bridge plug and whipstock will be set in the 9-5/8" casing at -2,750'. The intermediate hole is planned as a long string with the shoe set in the top of the Sag River Formation. The production interval will be completed with a cemented and perforated liner. The maximum anticipated surface pressure from the Ivishak/Sag with a full column of gas from TD to surface is -2,279 psi (assumes 7.13 ppg as max pore pressure and 0.1 psi/ft gas gradient). This well will be drilled by Doyon 14 using their 5,000 psi four preventer BOP stack A detailed operations summary is included with the permit application. Below is a brief summary of planned drilling operations. 1. Move in and rig up Doyon 14 2. Nipple up BOPE and test to 3,500 psi 3. Pull 5-1/2" tubing from -2,300' MD to surface 4. Set EZSV and whipstock, mill window in 9-5/8" casing. Perform LOT. 5. Drill 8-1/2" intermediate section to TSAG casing point 6. Run and cement 7" long string (TOC will be -V700' TVD above West Sak/Ugnu). Pressure test liner to 3,500 psi. 7. Drill 6-1/8" production interval to target Zone 2B sands. Geosteer as required. 8. Run and cement 4-1/2" production liner (TOC will be top of 4-1/2" liner top packer). Pressure test to 3,500 psi. 9. Run in hole with perforating assembly. Perforate 4-1/2" liner only after cement has reached 1,000 psi compressive strength. 10. Run 4-1/2" production tubing. Set the production packer and pressure test to 3,500 psi. 11. Freeze-protect and secure well. 12. Rig down and move off Doyon 14. In addition to a planned well summary, directional plan with anti-collision report and proposed completion diagram is attached to the permit application. If there are any questions concerning information on 07- 07C, please do not hesitate to use the contact information below. Brad Gorham Office: 907 564-4649 Cell: 907 250-3209 Email: Bradley.Gorhamc bp.com Attachments: 07-07B Wellbore Schematic 07-07B Proposed Pre-Rig Schematic 07-07C Proposed Completion Directional Plan Anti-collision Report As-Built Survey BOPE Equipment Schematics Well Head Schematic Tree Schematic 07-07C PTD Page 1 10/24/2014 • • Planned Well Summary Well 07-07C Well Producer Target Ivishak Type Objective Current Status 07-07B is currently shut-in due to high GOR Estimated Start Date: 12/31/2014 Time to Complete: 33.4 Days Surface Northing Easting Offsets TRS Location 5,949,574.79 676,067.20 1,346.95' FNL / 11N 14E sec 33 5,141.7' FWL Tie in Northing Easting Offsets TRS (Sidetrack 5949608.38 676065.78 1,313' FNL / 5,141.1' 11N 14E sec 33 point) FWL Northing Easting TVDss Offsets TRS Tgt 1 5 948,823.00 679,448.00 -8,474' TSGR 2,178.7' FNL / 3,222' 11N 14E Sec FWL 34 TSAD 5,948,802.00 679,513.00 -8,578' 2,201.3' FNL / 11N 14E Sec 3,287.0' FWL 34 BHL 5,946,810.00 683,267.00 -8,880' 4,283.1' FNL / 11N 14E Sec 1,709.3' FWL 35 Planned KOP: 2,750' MD / 2,687' Planned TD: 14,115' MD / 8,880' TVDss TVDss Rig: Doyon 14 GL-RT: 34.30 RTE (ref MSL): 60.87 Directional — Schlumberger P12 KOP: 2,750' MD Maximum Hole Angle: 33.93° in the 8-1/2" intermediate section 119.07 in the 6-1/8" production section 02-06, 02-06C, 02-26, 02-26A, 02-26APB1, 02-26APB2, 02-26B, 02-26C, Close Approach Wells: 07-02, 07-05, 07-07 -91' MD to -2,750' MD = GYD-GC-MS Survey Program: -2,750' MD to 3,100' MD = INC+TREND 3,100 MD to TD = MWD+IFR+MS-WOCA Nearest Property Line: 25,230' Nearest Well within Pool: -200' 07-07C PTD Page 2 10/24/2014 s I Formation Tops & Pore Pressure Estimate (SOR) Estimated Minimum Most Likely Formation Formation Top Pore Pressure Pore Pressure (TVDss) (EMW ppg) (EMW ppg) SV5(Above 2,619 8.35 8.40 Plan) KOP 2,687 8.35 8.40 SV4 2,738 8.35 8.40 SV3 3,282 8.35 8.40 SV2 3,513 • 8.35 8.40 ' SV1 3,883 • 8.35 9.70 UG4 4,454 8.35 9.70 UG3 4,692 8.35 9.70 UG1 5,145 8.35 9.70 WS2 5,781 8.35 9.70 WS1 5,951 . 8.35 9.70 . CM3 6,128 • 9.20 • 9.50 CM2 6,663 9.30 9.80 CM1 7,369 9.40 10.00 . THRZ 7,758 9.60 10.00 BHRZ 7,927 9.60 10.00 TPTR 8,013 6.69 9.16 BPTR 8,033 6.69 9.16 • LCU 8,033 9.60 10.00 TJC 8,033 9.60 10.00 TJB 8,222 9.60 10.00 TJA 8,320 9.60 10.00 TSGR 8,414 5.71 7.13 TSHU 8,450 6.90 7.13 TSAD 8,518 6.92 7.13 TCGL 8,694 6.92 7.13 BCGL 8,767 6.92 7.13 23SB 8,826 6.92 7.13 22TS 8,879 6.92 7.13 21TS 8,929 6.92 7.13 PGOC 8,958 6.92 7.13 HOT 8,990 6.92 7.13 TZ1 B(Below 9,006 6.92 7.13 Plan) Invert 8,987 Cross Fault 8,987 TDF(Below 8,997 6.92 7.14 Plan) TZ1B 9,000 6.92 7.14 Final Invert 9,000 (Toe) 21TS 8,958 6.92 7.14 PGOC(Toe) 8,930 6.92 7.14 22TS 8,914 6.92 7.14 23SB(Above 8,870 6.92 7.14 Plan) 07-07C PTD Page 3 10/24/2014 • Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. MD/TVDss MD/TVDss 8-1/2" 7" 26 L-80 VamTop HC 9,482' Surface 9,482'/8,418' 6-1/8" 4 %" 12.6 13Cr-85 VamTop 5,165' 8 950'/7,948' 14,115'/8,880' (-x150' lap) Tubing 41/2" 12.6 13Cr-85 VamTop 8,955' Surface 8,955'/7,950' (-5' into liner TBS) Mud Program Intermediate Mud Properties: LSND 8-1/2" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (ppg) KOP-3,650' MD 9.2 - 9.7 <17 18 -25 <8 NA <18 9 - 10 3,650' MD -7,300' MD 9.7 - 10.0 <17 18 -24 <8 NA <20 9 - 10 7,300' MD -9,482' MD 10.2 - 10.4 <20 18 -24 <4 <10 <20 9 - 10 Production Mud Properties: Water Based Polymer Fluid (PowerPro) 6-1/8" hole section r Depth Interval Density PV YP API FL Lo R teear MBT pH (ppg) (cp) (Ib/100ft2) Viscosity 9,482' MD -TD 8.4 -8.8 <12 10 -20 <10 >15,000 <4 8 - 10 Logging Program 8-1/2" Intermediate: Sample Catchers-as required by Geology Drilling: Dir/GR/Res Open Hole: None Cased Hole: None 6-'/8" Production: Sample Catchers-as required by Geology Drilling Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None Cement Program Casing Size 7" 26#, L-80 VAM TOP HC, Intermediate Liner Basis: Lead: Annular volume plus 40% excess, 80' shoe track Lead: TOC: 3,350' MD (-700' TVD above the Ugnu/West Sak DPZ) Tail: A tail slurry will be utilized due to the ECD's that will be induced on the cement job. Total Cement Spacer -45 bbls of Viscosified Spacer weighted to -11.5 ppg (Mud Push II) Volume: Lead 178.2 bbls, 1,000.08 ft', 854.8 sacks, 11.5 lb/gal LiteCRETE H- 1.17 fe/sack Tail 17.7 bbls, 99.37 ft', 91.4 sacks, 15.8 lb/gal Class G- 1.17 fe/sack Temp BHST 191° F Casing Size 4-1/2" 12.6#, 13Cr-85 VamTop, Production Liner Basis: Lead: Annular volume, 80' shoe track Lead: TOC: 8,950' MD (Top of 4-1/2" liner) 07-07C PTD Page 4 10/24/2014 S • Tail: None planned Total Cement Spacer -50 bbls of Viscosified Spacer weighted to -11.5 ppg (Mud Push II) Volume: Lead 87.6 bbls, 491.83 ft', 420.4 sacks 15.8 lb/gal Class G- 1.17 ft'/sk Temp BHST 197° F Surface and Anti-Collision Issues Surface Close Proximity: No wells will be affected by the Doyonl4 rig shadow. See below for shut-ins due to close approach. Sub-Surface Pressure Management: No wells will need to be shut-in due to pressure interactions. Anti-Collision: Nine Wells fail major risk but only three wells will need to be shut-in while drilling: ➢ 02-068- P&A'd due to sidetrack ➢ 02-26 - P&A'd due to sidetrack ➢ 02-26A/02-26APB1/02-26APB2 - P&A'd due to sidetrack ➢ 02-26C-effectively P&A'd as a CIBP was set at 12,515' MD and passed a PT. Since our potential intersection point is 12,890' MD, this well will no longer need to be shut-in. ➢ 07-02 -will need to be shut-in at surface prior to drilling out the 07-07C 7" shoe track and will need to remain shut-in until the production liner is cemented in place. ➢ 07-05 -will need to be shut-in at surface prior to drilling out the 07-07C 7" shoe track and will need to remain shut-in until the production liner is cemented in place. ➢ 07-07- P&A'd due to drilling of parallel well 07-07A. Hydrogen Sulfide DS-07 is not considered an H2S site. Recent H25 data from the pad is as follows: Well Name H2S Level Date of Reading Parent Well (if sidetrack) 07-07B #1 Closest SHL Well H2S Level 07-06B 20 ppm 3/31/2013 #2 Closest SHL Well H2S Level 07-08B 22 ppm 2/2/2014 #1 Closest BHL Well H2S Level 07-02B 28 ppm 3/31/2014 #2 Closest BHL Well H2S Level 02-06B 14 ppm 2/12/2014 #3 Closest BHL Well H2S Level 02-26C 20 ppm 5/20/2014 #4 Closest BHL Well H2S Level 02-25A 22 ppm 1/30/2012 Max Recorded H2S on Pad/Facility 07-24 50 ppm 5/15/2005 07-07C PTD Page 5 10/24/2014 • Faults Throw Formation Where MD TVDss Direction Lost Circ Encounter Fault Intersect Intersect and Uncertainty Potential Magnitude Fault#1 -Z2C 10,010.0 8,818.0 10-15'DTE 100' Low Fault#1 -Z2A 11,065.0 8,988.0 50-70'DTW 100' Low Drilling Waste Disposal • There is no annular injection in this well. i • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal/Contact the GPB Environmental Advisors (659-5893) f/guidance. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP test frequency for 07-07C will be 7 days during the de-complete phase. After a successful casing test and during the drilling phase, a full BOP test will occur every 14 days with a function test occurring every 7 days. Except in the event of a significant operational issues that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Intermediate Interval Maximum anticipated BHP 3,121 psi at the TSGR at 8,418' TVDss (7.13 ppg EMW) .- Maximum surface pressure 2,279 psi (.10 psi/ft gas gradient to surface) - 25 bbls with 13.1 ppg frac gradient Kick tolerance Assumes 7.13 ppg pore pressure in the TSGR + 0.5 ppg kick intensity and 10.2 ppg MW. Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 3,500 psi/250 psi 7" Casing 3,500 psi surface pressure Integrity Test—8-1/2" hole LOT after drilling 20'-50' from middle of window The 7" Casing Rams will be installed once the 9-5/8" casing cut and pull 7" Casing Rams is completed and will remain in the upper rams until the production interval. Production Interval Maximum anticipated BHP 3,321 psi at the PGOC at 8,958' TVDss (7.13 ppg EMW) J, Maximum surface pressure 2,426 psi (.10 psi/ft gas gradient to surface) / Infinite with >9.3 ppg frac gradient Kick tolerance Assumes an 7.13 ppg max pore pressure in the Ivishak + 0.5 ppg kick intensity and 8.6 ppg MW. 07-07C PTD Page 6 10/24/2014 �► ! Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 3,500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20'-50' of new hole 4-1/2" Liner Top Packer 3,500 psi surface pressure Planned completion fluids 8.4 - 8.5 ppg Seawater 07-07C General Operations Summary Proposed Drilling Rig Operations: 1. MIRU Doyon 14 2. Test TWC from below to 3,500 psi for 5 minutes. 3. Nipple down tree. Nipple up and test BOPE to 3,500 psi. 4. Pull TWC with lubricator. 5. RU hard lines to BOP. Circulate out diesel freeze protection (Arctic Pack) and displace well to clean seawater. 6. RU and pull the 5-1/2" tubing from the pre-rig cut. 7. PU and RIH with 9-5/8" clean out assembly down to the top of tubing stub. 8. RU E-line and RIH with USIT (CCL/GR) and log cut interval. 9. RIHwith EZSV, GR/CCL log and set EZSV(competent sand/confirm with GR) as required to avoid cutting a casing collar. Rig down E-line. 10. Pressure test the EZSV to 3,500 psi for 30 min. Chart test. 11. MU a 9-5/8" Baker cutting assembly. Cut the 9-5/8" casing above TOC as determined from USIT log. POOH and LD cutting assembly. 12. MU 9-5/8" casing spear assembly, RIH and unseat the 9-5/8" casing. 13. Pull and LD the 9-5/8" casing. 14. Pressure Test OA to 2,000 psi. 15. Change out upper rams to 7" casing rams and test 250 psi low/3500 psi high. 16. PU 9-5/8" whipstock, bottom trip anchor and 8.5"window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. c. 17. Hang off milling assembly on storm packer. Change 9-5/8" Pack-Off and Pressure test to 3,500 3 / —5�.Se psi. 18. Swap the well over to 9.0 ppg fresh water LSND milling fluid. 19. Mill window in the 9-5/8" casing plus 20' of formation. 20. Pull into 9-5/8"window and perform LOT. POOH for drilling BHA. 21. MU 8-1/2" drilling BHA with GR/RES/PWD and RIH. Drill 8-1/2" intermediate interval. -fl S p-r 07-07C PTD Page 7 10/24/2014 • • 22. Drill 8-1/2" intermediate interval to section TD in TSGR. Weight up drilling fluid using spike fluid following the PPFG density ranges. 23. At TSGR, CBU until hole is clean (minimum 2x) and perform short trip to the window. 24. RIH to TD, circulate well clean, and POH on elevators. 25. Run 7", 26#, L-80, VAM TOP long string to TD. Set 7" 26#, L-80, VAM TOP on slips. 26. Cement 7", 26#, L-80 VAM TOP for zonal isolation. Circulate out cement with mud. POOH. 27. Change upper 7" casing rams to 2-7/8" x 5-1/2" VBR pipe rams and test to 250 psi low/ 3500 psi high. 28. MU 6-W drilling BHA with GR/RES/NEU/DEN. RIH to the landing collar and test the casing to 3500 psi for 30 minutes. 29. Displace the well to 8.6 ppg Power-Pro SF fluid prior to fully drilling out shoe track 30. Drill out the 7" shoe plus 20' of new formation. Pull into the shoe and perform a FIT. 31. Drill 6-1/8" production hole to TD as per directional plan. ,. 32. Circulate bottom ups and condition the hole as necessary. 33. Short trip BHA to 7" shoe pulling on elevators 34. Trip in hole to TD and circulate/condition the hole as necessary until shakers clean up. POOH on elevators. 35. MU and run 4-W 12.6# 13CR VamTop liner to TD. 36. Fully cement the liner to the TOL with 15.8 ppg Class G cement. 37. Set liner top packer and displace well to clean seawater above the liner top. 38. Pressure test casing and liner to 3,500 psi for 30 minutes. 39. POH, L/D the liner running tool. 40. RU DPC perf guns, RIH and perforate. 41. R/U and run a 4-'/2", 12.6#, 13CR, VAMTOP tubing completion with GLMS. Space out and land the tubing with tubing tail inserted into the liner tieback sleeve. 42. Space out and make up tubing hanger per Cameron Rep. Land the tubing hanger, and run in lock down screws. 43. Displace tubing and IA to 8.8 ppg brine and reverse circulate with corrosion inhibitor(surface to surface). 44. Drop ball and rod. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 45. Shear the DCR valve. 46. With landing joint still rigged up, reverse circulate diesel freeze protect using rig injection pump. 07-07C PTD Page 8 10/24/2014 • 47. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. 48. Install TWC and test from above to 250 psi low/3,500 psi high for 5 minutes each and from below to 250 psi low/3,500 psi high for 5 minutes low/5 minutes high. 49. Nipple down the BOPE. Nipple up the adaptor flange and double master valves and test to 5,000 psi with diesel. 50. Install all annulus valves and secure the well. 51. RDMO. Planned Post-Riq Operations: 1. MI/ RU Slickline. Pull TWC, ball and rod and RHC Plug. 2. Pull shear valve and dummies, install GLVs. 3. Obtain SBHP 4. Flowback per ASRC 5. Modify S-Riser as required. 6. Install flow lines and well house. 07-07C PTD Page 9 10/24/2014 • • 07-07C Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: / A. Intermediate Hole: Possible overpressure in the Put River formation. The PPFG will be strictly followed to mitigate the overpressure if it is encountered. B. Production Hole: The Ivishak is expected to be at a 7.13 ppg EMW. Reservoir pressures will be controlled by using 8.4—8.8 ppg water based mud thought out the production interval. II. Lost Circulation/Breathing A. Intermediate Hole: There are no expected fault crossings in the intermediate hole section. Be aware of drilling ECD's as recent wells have encountered breathing in the intermediate section. B. Production Hole: Two fault crossings are planned in the production hole. Lost circulation is - considered a low risk as other wells have crossed these faults and had minimal history of lost circulation. . III. Fault Locations Formation Where MD TVDss Throw Direction Uncertainty Lost Circ Encounter Fault Intersect Intersect and Magnitude Potential Zone 2C 10,010.0 8,818.0 10-15' DTE 100' Low Zone 2A 11,065.0 8,988.0 50-70' DTW 100' Low IV. Integrity Testing Test Point Test Depth Test type EMW(lb/gal) 9-5/8"window 20'-50' from the 9-5/8"window LOT 13.1 ppg 7" shoe 20'-50' from the 7" shoe FIT 9.3 ppg V. Hydrogen Sulfide A. DS-07 is not considered an H2S site. Recent H2S data from the Pad is as follows: Well Name H2S Level Date of Reading Parent Well (if sidetrack) 07-07B #1 Closest SHL Well H2S Level 07-06B 20 ppm , 3/31/2013 #2 Closest SHL Well H2S Level 07-08B 22 ppm 2/2/2014 #1 Closest BHL Well H2S Level 07-02B 28 ppm s 3/31/2014 #2 Closest BHL Well H2S Level 02-06B 14 ppm 2/12/2014 #3 Closest BHL Well H2S Level 02-26C 20 ppm 5/20/2014 #4 Closest BHL Well H2S Level 02-25A 22 ppm 1/30/2012 Max Recorded H2S on Pad/Facility 07-24 50 ppm / 5/15/2005 VI. Anti-Collision Issues Nine Wells fail major risk but only three wells will need to be shut-in while drilling: ➢ 02-06B— P&A'd due to sidetrack ➢ 02-26 - P&A'd due to sidetrack ➢ 02-26A/02-26APB1/02-26APB2 - P&A'd due to sidetrack ➢ 02-26C -will need to be shut-in at surface prior to drilling out the 07-07C 7" shoe track and will need to remain shut-in until the production liner is cemented in place. ➢ 07-02 -will need to be shut-in at surface prior to drilling out the 07-07C 7" shoe track and will need to remain shut-in until the production liner is cemented in place. ➢ 07-05-will need to be shut-in at surface prior to drilling out the 07-07C 7" shoe track and will need to remain shut-in until the production liner is cemented in place. ➢ 07-07— P&A'd due to drilling of parallel well 07-07A. CONSULT THE DS-07 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 07-07C PTD Page 10 10/24/2014 WE AD_ GRAY GRAY F • 07-07 B I SA NOTES: WELL 70°c 10833'. ACTUATOR= AXIISON NfIAL KB_F1 F 64' I I BF.B.EV= _2 _....----(: KOP= 2800' 20"CONDUCTOR, -{ 2130' I—5-1/2"CAMCO BAL-O SSSV NP,D=4.562" Max Angle= 95°@ 11018' 91.5#,14-40, I Datum MD= 10633' D=19.124" GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT [GATE 1 2897 2893 14 MAC DM' RK 0 04/20/08 HALBURTON DPW PATCH, --I 1102'-1122' , 2 5049 4727 36 MMC' DMY RK 0 04/20/08 D=2.987'(10/29/08) 3 6676 5962 43 MM3 DMV RK 0 03/30183 13-3/8°CSG,72#,L-80,ID=12.347" -- 2496' 4 7837 6833 40 144u43 DMY we 0 03/30/83 5 7902 6883 41 KING DMY RK 0 03/30/83 6 8522 7349 43 MM3 DMY RK 0 03/30183 HALBURTON DPW PATCH ID=2.987" —I 6894'-6914' 7 8594 7402 43 MM3 DMY RK 0 03/30183 (SET 10/29/08) I 8 9043 7729 43 MM3 DMY RK 0 03/30183 9 9114 7781 43 Mut3 DMY R1< 0 03/30/83 10 9428 8007 44 MM3 DMY RK 0 03/30/83 Minimum ID = 2.377" @ 10928' 11 9501 8059 45 MM3 DMY RKED 0 03/30/83 3-3/16" X 2-7/8" XO 9565' —I4"BOT DB'LOY SLV w/GS PROF,ID=3.00 9571' —14"X3-1/2" XO,D=2.972" J9575' H5-1/2"BKR PBR ASSY(BEHIND PIPE) 9581' H9-5/8"X 5-1/2"BKR SAB PKR(BEHIND PIPE) i v. 9584' H3-1/2"PX PLUG(04/19/13) 5-1/2"TBG-PC,17#,L-80,.0232 bpf,D=4.892" —j 9592' A 9584' --13-1/2"HOMO X NP,D=2.813" 9592' I—5-1/2"X 4-1/2"XO(BBiiND PIPE) 3-1/2"LNR,9.2#,L-80,STL,.0087 bpf,ID=2.992" —I 9614' I-- -s"--------i 9614' H 3-1/2"X 3-3/16"XO,D=2.786' TOP OF 7"LNR — 9621' i 9652' H4-1/2"CAMCO DB-6 NIP,D=3.813" 9663' —14-1/2"BKR SHEAROUT SUB BERND 4-1/2"TBG-PC,12.6#,L-80,.0152 bpf,D=3.958" --I 9664' I 9664' H41/2"TUBING TAI.,D=4.00" PIPE 9-5/8"CSG,47#,L-80,D=8.681" --I 9923' 16 9657' HH—m°TT LOGGGHI 05/28/89 1.•.. ,,•, 10325' —I EST TOP OF CEMENT �•• ••• .••• •• 7"MECHANICAL WHPSTOCK(06/21/06) —I 10510' Vii! •� ML.LOUT WNDOW(07-078) 10509'-10514' .• RA PP TAG —f 10521' I— ;,:a''' ,.'4 •••i 10928' H 3-3/16"X 2-7/8" XO, i•••• •4 ♦••••• ••••••f / D=2.377" •••••• PERFORATION SUMIARY •••••••••�••,4 .••••••••••f• REF LOG:P NJ CCU GR ON 06/28/06 ••••••4 #••••••••••« ANGLE AT TOP PERE:920 @ 11120' !••••••••••i 12760' -I PBTD �••••• ` ♦••••4, Note:Refer to Production DB for historical perf data •••••••••••i PF INTERVAL '• ••••••• 3-3/16"LNR,6.2#,L-80, — 10928' 4144*••••t SCE SIT Opn/Sqz SHDT 1 SQZ ••••• �••••♦ SEEPAGE 2 FOR PERFORATION DATA •♦•••• STL,.0076 bpf,D=2.80" •••••••. ,• ••••••••� ' 3 I 1 1 I •.••••4 .••••• •••••••••••4 ••••••4 ••••4 2-7/8"LNR,6.16#,L-80, 12797' !••••• STL,.0058 bpf,D=2.441" ��••$••••••� 7"LNR,29#,L-80,.0371 bpf,D=6.184" -J10947' •Y•V•Y•A•j•V•' 0.••••V TD — 12870' DATE REV BY COMMENTS DATE REV BY COMvE NTS PFU)HOE BAY UVF 03/31/83 IINTIAL(07-07A) 10/21/14 PJC CONDUCTOR CORRECTION WELL: 07-078 06/30/06 NORDIC 1 CTD(07-078) 10/21/14 TR/JM) MSC CORRECTIONS FEF AT No:"2060810 10/13/08 JKDrPJC SET PATOIS(09/29/08) API No: 50-029-20901-02 03/18/10 OFC/SV SET PJC PLUG(03/10/10) SEC 33,T11N,R14E,1347'FTV_&138'F8 10/02/12 TUJM] PATCH DEPTH CORRECTIONS 04/25/13 MSS/JM7I RUN FSC PLUG(04/19/13) BP Exploration(Alaska) • 07-07B • : C 1 li-- . - iI II PERFORATION SUMAARY L ►;•� REF LOG:WCNJ ccu GR ON 06/2s/06 • � 4. ANGLE AT TOP PERF:92°@ 11120' bg Note:Refer to Production DB for historical perf data ��--Ai. SIZE SPF INTERVAL Opn/Sqz SHOT SQZ �� 2 6 11120-11170 0 06/29/06 �••••••••••1 :❖.•4 4 2 6 11210- 11330 0 06/29/06 i•••••••••, 2 6 11380-11510 0 06/29/06 j•••••••••• i••••• 2 6 11590-11920 0 06/29/06 i•�•�•�•�•! •••••• 2 6 12040-12200 0 06/29/06 •.•••• •••••• ••••• ••••••. 2 6 12260-12600 0 06/29/06 , �••••• ••••••••••• 2 6 12690-12756 0 06/29/06 •••••••••••. ••••••••••• •••••. ••♦•••♦••♦♦• '••• P••••••.*?4 .*••••••••••l DATE REV BY COMvB4TS DATE REV BY COMINJS PRUDHOE BAY MO 03/31/83 INITIAL(07-07A) 10/21/14 PJC CONDUCTOR CORRECTION WELL: 07-07B 06/30/06 NORDIC 1 CTD(07-07B) 10/21/14 TR/JM) MSC CORRECTIONS PERMT No:l'060810 10/13/08 JKIYPJC SET PATCI-IS(09/29/08) API No: 50-029-20901-02 03/18/10 OFC/SV SET PX PLUG(03/10/10) SEC 33,T11N,R14E,1347'FT&&138'FEL 10/02/12 TUJMO PATCH DEPTH CORRECTIONS 04/25/13 tv S/JMJ RUN PX PLUG(04/19/13) BP Exploration(Alaska) TREE. GRAY GEN3 • VitiLlEAD= GRAY 07-07B 7.--1lik ,.. WM L Tom 0 ibint. Acnskiok= AXEISCIN PROPOSED P&A unkt G, 19..E br EIF" ELEV, 7 ,------. oibr- mow 2Ir(.01VUICTOR, -40 1 MU 44.40- 95'I§limy vim,ii40, NAM IC..=. iSS37 ID=19,ur 1 0 I Delkin 1406 At- - - 0107 SS 44AUBLI010010PW PAWN _Filer-lizr L D=2.8er mama) ,.....--, -3,000 . Jet Tubing Cut LItioregn 778 1,88 in.ofkir H 241101 HAMPTON CIWPATCH,0=2 oar --1 6594;-0914 j ASE1 11129061 Proposed TOC — -8,500 ; iftrrik--migel ' - 1 NSW I 4".SOT OEFLOV MY*a I CS MCC,LI 4 300 0 i , 957V H41"X 1,1,7 NO,V144 2 972` )* 1 11575' H54/2"am MR ASSY(MIND pre) 1 050r H0-5/6"X 51-147-41104 SAS 445,019114919 Me ' 4 •A'auo-, ISM-F- '1—I/T PS MUG 011/19/13) 7 I ------'---1 5-tor VIG.PC.171.L-80.11232 bpl.V-tier H Hier ! AIHr- ---__ I eger H3-11/7 Howrox 1421,0 a 2 Sir 1 ' ' 7------1 mor H5-1r2 X 4-lIT 90111ENINDIMPI)1 I 3-vr umear,8.431a,sii JO67 bpi;CO=aser H.... 0014* 9$14' HS-yr X 3-311r xo.V Ak 2,701r I 1212f OF runi-L sew . .4 li , Mr I I4- ' 0............... 1 90141° yr MR i 4 1/T18G . ,2.60 LSD, .5152 644,D a 3.85r low "' tt, I mar Ifr TU310 1.17114-47 C=A;k7UTCtL:DI T.SISC4":.IWM:' 1 474 L-50,Do$19599-1 992J" ' 14 I 91PIT HELLO TT LOGGGEE 092019 I 10321'J--fen TOP OF CEMENT ••k , ... •1 •• . .4 - *..1 •* ' '44 1 Ir.msailkscALIA111;57004(50/29195) liwi rtALLourimpiDOW0114714 10616°-10524' pi 3=Tm .-.13 .1 :0621 - . .,, .. ,, -.--. -..-• • t 1092*' 1-3-sir x 2.mr xa •••••••• . •••••• ••••••, .. 7- 0.1377- •••••.- •••••• PRIFORAMP451.61644Re •••••4 41••••• -., •••••4' •••••• FIEF LOG WM/ati OR 00405/25095 •••••4 •••••• ., •••••44 ism, Pe", AMR*AY TOP PEW*roll va •••••• •••••4 •••••• ••••• We:Mier ID Pratm CO for bilintimiporf dffti •••••••• • 4 • •4 •••••• WEJ 9170 1 1111191AL I Opriiikg I SHOT j Soz : ••••••••••4, 34Bir tlift 6,211.L-10, 109 20* i - - SEE PAGE 2 FOR 713,4 EVVTA ::::::: , 8 T4., 0 0 7 0 b p 1 V=2,0 0' L.,____ 1 1 I •••••4 •••••• •••••4 •••••• •••••, ..tvin 247 1-44R,6 160,,1.40. 1279T W -- ••:+:44 SR.OM bpi.V=2..441.- I r L .210 t-ak rri3bvtv, :5 1134- !---1 1094r 'WWI •••••••• ID 12117, W 0A TE REV BY (TY/A*40S DATE RIN BY MOSPRAITS R0/11-1BF BAY Mr 11101011 opso COMM F11004 10013104 SOW SET PATCH'S g0102940 VEIL 07-0/9 11341113 LAST 1901140VER mono moo sum:Luc;(0311011() MAE Ns: 2093010 gems woLlic LE-9M____ mug 11.4*0 PAtOtarOitOPARAIMS Ap Sr 50.021121190i 02 MOM Mei Me %V 00 04/2913 UMW 1414 PC PLUS g4fl51131 SIX 34‘T1 MAE 13331 sic&142'rJ- UMW WARM -OW MOT c0F01=t49 rattim ' Pad A0043110LITOR DSO 9440100 WEN QIN 17/0(041201191) BP Et0oratio*(Al .„, _ CRAY GRAY PRO PO L 07-07C sa worFs: A = AXH.SON KE REV= 70' , BF aEv= ? _-CONDUCTOR. -{ 7 I-- K W= 2t #. � 49(4980r 1 a A _ 17— 4-1/2" HES X NIP, ID=3.813"DalmiJI TOP OF 7"LNR — E IW= Ma SS 13-3/8"CSG,72#, L-80 ID= 12.347"H 2496' 2352I— Full Open Collar 9-5/8"WHIPSTOCK(_/_/ ) —-2750' 2478 Full Open Collar 9-5/8"CSG,47#, L-80, ID=8.681" H-2759' 2775' MILLOUT WINDOW(07-07C) 2739 -2749 GAS LFT WAt1 H.S ST 1 M) TVD DEV TYPE VLV LATCH PORT DATE TOP OF CEMENT(3260')TVD —–3350' It f 4 hi.-. r Ile ilt 2 f r ilk 1i HALLIBURTON ES CEMENTER -6900' f 4-1/2"HES X NIP, ID=3.813" BAKER ECP „HI-6950' I 1!, ►, ... rrr� v ,f -8800' 7"X 4-1/2"HES TNT PKR, ID=3.870" 1 4=1/2"HES X NIP, ID=3.813" e. _ 4-1/2"HES XN NIP, ID=3.750" 14-1/2"TBG, 12.6#, 13CR-85 VAM TOP,.0152 bpf, ID=3.958" – –8945' 11t it 8940' 7"X 5" BKR TIEBACK SLV, ID= iii 0 TOP OF 4-1/2"LNR CEMENTED -8950' Ei :4 -8945' —14-1/2"WLEG, ID=3.958" .a, –8950 H7"X 5"BKR ZXPN LTP, ID= 1i 'Xf,IG L9482'"LNR,26#,L-80 VAM TOP HC, .0383 BPF, ID=6.276" 1—_ cc .01r oil •.1ti..;I TBD t RA TAG FERFOR4TlON 5I_1+,MAK1 ! <: REF LOG. ON 1 1 Fyi • ANSI FATTOPF RP.2'ep IN Nolo_Refer to Roducticn CB for hislarical perf data WE. `Sl I- NI EWA L Caprb'Sgz SI-10 I c SW ? ll `�` • TBD RA TAG t iii pi, r.v.v.voi PBTD 14.444.4.: ��.4..4..4t'1 -14,115' 4-1/2"LNR, 12.6#, 13CR-85 VAM TOP, .0152 bpf, ID=3.958" DATE Ir-if BY CO M NFS MSC PLV SY COMMITS FRIJOHOLBA" UNI 01101179 OI GCOMPLETION 10/1,1'06 JKLFJC SCTPATCIf510329108) Y41L. 07-07f3 03131/83 LAST WORKOVf34 D3/18110' OPOSV SET PJC PLUG 103,10/10) Pf33MT rib. 2080810 0613#1106 NIXIDIC 1 CTO(13') 1M12112 J 'UJ4. 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J A N m J J N M LL01 N J N LL LL V) NLL M 0 0(0 -00N-Ch C M M M m X o(n0 m N00m 0 -ow..0(p00N G N C OJ 4 n O 0 4 0 0 4O MO NO N0OC)O K64,6 c0 0) N 00�r NNO cr)O .� m m0 m m nrm00 m 0)000 NMMM MMMMM .0) @� • a M 0 J N 0) i0 O U m z0 Z O 0c-.3.0 00 ti 00 pv U W U Hm W 01- 2 a N W 0 ------._.___„_..a,.... ..._._ .- b p 0 Schlumberger Borehole: Well: Field: Structure: DS07-07C(P2b) 07-07A Prudhoe Bay Unit-BOA DS-07 Gravity 8 Magnetic Parameters Surface Location NAD27 Alaska State Plane,Zone 04,US Feet Miscellaneous Model: BGGM 2014 Dip:80.995° Date: 20-Jan-2015 Lat: N 7016 4.21 Northing: :949574.79ftU Grid Cony: 1.3403° Slot: 07-07A TVD Ref: Rotary Table(60.87ft above MSL) MagDec:19.505° FS: 57590.527nT Gravity FS: 1001.998mgn(9.80665 Based) Lon: W 148 34 34.22 Fasting: 676067.2ftUS Scale Fact: 0.99993522 Plan:07-07C(P2b) 0 1000 2000 3000 4000 5000 6000 7000 8000 0 KBE 0 OMD 1000 1000 2000 13-3'8' 2000 248]MD Tie-In Survey 2691 MO Top Whipstock • 27.60 Base Whipstock • 2786 MD 'sVa i379e:8YYv6'j .. .Cry 3.`5/100 3000 2786 M° 3000 Cis 2080 MD 0 2886 MD _7._1._.._.._.._.._.. .._.._.._.._.._._n._.._.._.._.._.._.._.._.._.._:._.._.._.._.._.._.._.._...._.._.._.._.._.._.._.._...._.._.._.._.._.._.._.._...._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..�.._.._.._.. 5703(3342.8]TVD) End Cry : 3500 MD svi(J3Y3 8]TVb)_.._.... ._.._.._.._.._.._:._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..:.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.. 4000 SV1iOS43.81CVb) __.. ._.._._.._.._.._.._ _.._.._.. ._ _.._.._._ _.._.._ ._.._.._. ._._..,.._.._ _.._.._.. .. .._.._.._ .._.._.._.._.._.. _._. _.._.._._ .._.._.. 4000 '- 0 to u) CC414314.Br1S)_.._.._.._.._.._._.._.._._.._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._-._.._. 11 lJC3(47$2 BriVb) _.._.._.._.._.._._.._.._...._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._...._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..:.._.._.._.._.._.._.._.._....._.._.._.. d u 5000 ................_._... 5000 0) l^1GT(520ftirlVD) .._.._.._.._.._.._.._.._ _.._.._..__.._.._.._.._.._:._.._.._.._.._.._.._.._.._..._.._.._.._.._.._.._.._....._.._.._.._.._.._.._.._....._.._.._.._.._.._.._.._..i.._.._.._.._.._.._.._.._..�.._.._.._.._.._.._.._.._....._.._.._.. o • 3/100 > - 6609 MD F • ._._.._.. .._.._.._.. ._..__.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._...._.._.._.._.._.._.._.._....._.._.._.._.._.._.._.._.._.._.._.._.. 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OF GEGLAK WES 60X = 2 6. 5 7 - • PAO r-----PROTRA C TE0 sEc. 33 e 34 7-11/V, R 14E U.M. `�,�6�Ze1 _ .5C At E= 1'' _ -400' .�' ..9.-N.4_S t� I HEREBY CERTIFY THAT I AM i -co: • '�.�I PROPERLY REGISTERED AND; 4-: .'1 _ `_ RTy s LICENSED TO PRACTICE LAND! '' - •••• " ° SURVEYING IN THE STATE OF' s `ALASKA AND THAT THIS PLAT (1, ' LOREN M. SEI - '�''"'�' . '8�I REPRESENTS AN AS-BUILT SURVEYS • +, (, .. NO. 3822-S ;•��i • Alaska C; , �s MADE BY ME, AND THAT ALL( � r,••. . �+ nl,". !��Gc..,U:�n':. �Onlf1"iIS^,IJi, I DIMENSIONS AND OTHER DETAILS #41 %, ssitta `., . A.^ ilorayc ARE CORRECT, AS OF: 2-23-631 3 I ' /�i�,41'1iNBY: 83 .._.. \ ISS. x/7,4 AS-TILT _ - sHT. - Ch/ECKEO 5Y- ___._ _ _ OA TE: FEB.23,/983 • - - _ 1 EL: �<� = = ARC0 AlaskaInc / IlitTREE= GRAY GEN 3 WELLHEAD= GRAY SA NOTES: WELL 70°@ 10833' ACTUATOR= AXELSON 0 7-0 7 B KB.ELEV= 70' BF.ELEV= _? KOP= 2800' Max Angle= 95 @ 11018' 2130' H5-1/2"CAMCO BAL-O SSSV NP,ID=4.562" Datum MD= 10633' • GAS LFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 2897 2893 14 NTNG DOME RK 16 07/04/06 13-3/8"CSG,724,L-80,ID=12.347" H 2496' HA 2 5049 4727 36 MMG SO RK 20 07/04/06 3 6676 5962 43 MMG DMY RK 0 03/30/83 4 7837 6833 40 MMG DMY RK 0 03/30/83 5 7902 6883 41 MMG DMY RK 0 03/30/83 Minimum ID = 2"377" @ 10928' 6 8522 7349 43 MMG DMY RK 0 03/30/83 3-3/16" X 2-7/8" XO 7 8594 7402 43 MMG DMY RK 0 03/30/83 8 9043 7729 43 MMG DMY RK 0 03/30/83 9 9114 7781 43 MMG DMY RK 0 03/30/83 10 9428 8007 44 MMG DMY RK 0 03/30/83 11 9501 8059 45 MMG 01W RKED 0 03/30/83 9565' —4"BOT DEPLOY SLV W/GS PROF,ID=3.00 9571' --I4"X 3-1/2" XO,ID 9575' —15-1/2"BKR PBR ASSY(BEHIND PIPE) 110 109581' —19-5/8"X 5-1/2"BKR SAB PKR(BEHIND PIPE) 9584' —I 3-1/2"HOWCO X NIP, 7=2.813" 5-112"TBG-PC,17#,L-80,.0232 bpf,ID=4.892" —I 9592' I 9592' —15-1/2"X 4-1/2"x0(BEHIND PIPE) 3-1/2"LNR,9.24,L-80.5-R_,.0087 bpf,ID=2,992" 9614' 9614' —3-1/2"X 3-3/16"XO,ID=2.786" TOP OF 7"LNR —i 9621' I 9652' —4-1/2"CA MCO DB-6 NP,ID=3.813" 9663' --14-1/2"BKR SHEA ROUT SUB BAND 4-1/2"TBG-PC;12.6#,L-80, .0152 bpf,ID=3.958" — 9664' 9664' 14-1/2"TUBING TAIL,ID=4.00" PIPE 9-5/8"CSG,474,L-80,ID=8.681" —I 9923' 9657' {ELMD TT LOGGGED 05/28/89 10325' 'HEST TOP OF CEMENT 744 ;• ' 4 M 7"MECHANICAL WHIPSTOCK(06/20/06) 10511' 4 4 •'••4.` MLLOUT WINDOW(07.07B) 10516'-10524' • RA PIP TAG --I 10521' •':-Oki !r'• : 10928' I—3-3/16"X 2-7/8" XO, • •4' ..... ID=2.377,. ♦ 1.444. •4.444.�� PERFORATION SUMMARY 0444 �♦r REF LOG:MCNL/CCU GR ON 06/28/06 j4•j4"-•-• �� 12762' -{PBTD 44.414 ‘....♦ ANGLE AT TOP PERE:92 @ 11120' j.444444 Note:Refer to Production DB for historical erf data •444 � � P . • 4t 3-3/16"LNR 6.2#,L-80, 10928' Nw SIZE SPF INTERVAL O n/S z DATE x.4444 NIPp 4 P�4�4�4�4�44 STL,.0076 bpf;ID=2.80" SEE PAGE 2 FOR PERFORATION DATA : �(' s;;,� I l ♦44444 , •�.�.+.fir' 2-7'8"LNR,6.164,L-80, —i 12797' X4.444 �4444�44.444 STL,.0058 bpf,ID=2.441" �a�t..� p i�� • TD 12870' ►'1'19''`'1 7"LNR,294,L-80,.0371 bpf,ID=6.184" 10947' 1�J•`A•AAi DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/04/79 ORIG COMPLETION WELL 07-078 03/31/83 LAST WORKOVER PERMET No:'2060810 06/30(06 NORDIC 1 CTD("B") API No: 50-029-20901-02 07/04/06 KSB/PAG GLV C/O SEC 33,T11N,R14E,981.91'FEL&4224.11'FNL d 03/03/07 DRF/PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) • Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumberger 6411 A Street Anchorage, AK 99518 Tel (907)273-1700 Monday October 20, 2014 Brad Gorham PBU EOA DS07-07C (P2b) BP Exploration (Alaska) Inc. Doyon 14 Close Approach Analysis We have examined the potential intersections of the subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook(BPA-D-004)dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two hundred feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. 3. All depths are relative to the planned well profile. Survey Program: Please see BP survey program on the anti-collision summary Survey Interval Intermediate hole: 1 per stand — 93 ft(except where planned/actual dls is 5/100 or greater) Production hole: 1 per stand — 93 ft(except where planned/actual dls is 5/100 or greater) Close Approach Analysis results: Under method (2), note: 02-06B, 02-26/26APB1/APB2/26B/26C, and 07-07 fail the major risk rule. They pass a risk rule of 1:10 07-02B and 07-05 fail the major risk rule. They pass a risk rule of 1:20. The BP TCRW's are at the client office. Rule sets are used per the client. There is potential to see magnetic interference from the planned KOP of 2750'md to±3100'md. All data documenting these procedures is available for inspection at the Drilling & Measurements Drilling Engineering Center(DEC). Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder plot will be provided. Checked by: Scott DeLapp 10/20/2014 • • CO' Mill I O N CO 111 M O liii N 111141111111 Ill M I :o I o INITIM L L oM { 1 Ell h. N 1 c p M to LO k O I 0 a QN m n I cn I O CO IMINEMIIIL 4 O n j �j O 2 P 0 N LC) 1 MI _ o m N N- U o p U^ - co m^ OO I N O O -, Lo -2 O C C , N _ O p .oma>_o"� o 1 O I I I I I I I I 1 I I I I 1 1 I I I 1 1 I 1 1 1 1 I I I I I I 1 1 1 1 I 1 1 1 1 I I I I I I I I I I I I I I I I I I I 1 I 1 1 1 1 I I I I I O l[) O t) O )() O O Lc> O N O o n c0 c0 N In V V co M N N (uiil4sn 00 uoquasdas aqua° of ague° • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-07A Project: Prudhoe Bay ND Reference: 07-07C @ 60.87usft(D14 plan) Reference Site: PB DS 07 MD Reference: 07-07C @ 60.87usft(D14 plan) Site Error: 0.00usft North Reference: True Reference Well: 07-07A Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 07-07C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#2b 07-07C Offset ND Reference: Offset Datum Reference Plan#2b 07-07C Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 5.00usft Error Model: ISCWSA Depth Range: 2,690.87 to 14,115.52usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,608.12usft Error Surface: Elliptical Conic Survey Tool Program Date 10/21/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 90.87 2,690.87 07-07A Srvy 2 GYD-GC-MS(07-07A) GYD-GC-MS Gyrodata gyrocompassing m/s 2,690.87 2,750.00 Plan#2b 07-07C(Plan 07-07C) GYD-GC-MS Gyrodata gyrocompassing m/s 2,750.00 3,100.00 Plan#2b 07-07C(Plan 07-07C) INC+TREND Inclinometer+known azi trend 3,100.00 4,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 4,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 4,600.00 5,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 5,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,100.00 5,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 5,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 5,600.00 6,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 6,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 6,100.00 6,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 6,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 6,600.00 7,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 7,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 7,100.00 7,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 7,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 7,600.00 8,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 8,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,100.00 8,600.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 8,600.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 8,600.00 9,100.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 9,100.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/0 Crustal 9,100.00 9,480.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 3,100.00 9,480.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,480.00 11,000.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 11,000.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 11,000.00 11,500.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 11,500.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/0 Crustal 11,500.00 12,000.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 12,000.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 12,000.00 12,500.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 12,500.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/0 Crustal 12,500.00 13,000.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 13,000.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 13,000.00 13,500.00 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 13,500.00 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 13,500.00 14,115.52 Plan#2b 07-07C(Plan 07-07C) MWD MWD-Standard 9,480.00 14,115.52 Plan#2b 07-07C(Plan 07-07C) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 10/22/2014 12:01:08PM Page 2 of 5 COMPASS 5000.1 Build 61 • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-07A Project: Prudhoe Bay ND Reference: 07-07C @ 60.87usft(D14 plan) Reference Site: PB DS 07 MD Reference: 07-07C @ 60.87usft(D14 plan) Site Error: 0.00usft North Reference: True Reference Well: 07-07A Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 07-07C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#2b 07-07C Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 02 ( 02-06-02-06-02-06 13,568.98 11,705.00 568.22 243.34 327.24 Pass-Major Risk 'f"A 02-06-02-06A-02-06A 12,918.66 12,307.00 463.15 273.31 189.67 Pass-Major Risk} W,A.1 Of v-55 t 02-06-02-069-02-06B 13,601.19 12,100.00 61.41 14.80 58.33 Pass-Minor 1/10 02-06-02-06C-02-06C 13,608.67 11,470.00 773.93 246.40 528.68 Pass-Major Risk 02-26-02-26-02-26 11,871.18 11,160.00 530.92 11.04 530.37 Pass-Minor 1/10 02-26-02-26A-02-26A 11,924.64 10,925.00 597.76 2.38 596.49 Pass-Minor 1/10 .I--- 02-26-02-26APB1-02-26APB1 11,906.74 10,955.00 593.29 2.53 591.87 Pass-Minor 1/10 - Y 02-26-02-26APB2-02-26APB2 11,898.56 10,970.00 592.47 2.54 591.04 Pass-Minor 1/10 l'1'1 A)t 02-26-02-269-02-269 11,890.23 10,755.00 1,088.99 2.54 1,087.14 Pass-Minor 1/10 ) `4 02-26-02-26C-02-26C 10,209.74 12,890.00 142.45 11.85 133.60 Pass-Minor 1/10 PB DS 07 07-02-07-02-07-02 4,512.48 4,435.00 442.33 171.27 287.48 Pass-Major Risk 07-02-07-02A-07-02A 12,586.06 12,075.00 478.59 298.38 188.67 Pass-Major Risk 1 A i 1 07-02-07-02B-07-02B 10,296.14 11,915.00 215.21 3.72 214.76 Pass-Minor 1/20 07-03-,07--0-3---07:03- 3,176.26 3,165.00 511.01 146.67 364.27 Pass--Major Risk M j Uv' 07-03-07-03A-07-03A 3,177.10 3,160.00 511.18 146.84 364.28 Pass-Major Risk Sri 5 07-03-07-03APB1-07-03APB1 3,177.10 3,160.00 511.18 146.84 364.28 Pass-Major Risk 07-04-07-04-07-04 3,261.46 3,240.00 363.67 184.34 179.30 Pass-Major Risk 07-04-07-04A-07-04A 3,261.46 3,240.00 363.67 184.34 179.30 Pass-Major Risk r 07-05-07-05-07-05 3,945.27 3,950.00 100.92 1.98 99.21 Pass-Minor 1/20 - 07-06-07-06-07-06 3,135.56 3,140.00 149.47 145.37 9.47 Pte-Major Risk 1A r`.U'' 07-06-07-06A-07-06A 3,135.56 3,140.00 149.47 145.37 9.47 Pass-Major Risk f l �� 07-06-07-06B-07-06B 3,134.64 3,130.00 149.36 145.19 9.47 Pass-Major Risk 07 07 07 07 07 07 2,692.65 2,695.00 12.79 4.95 7.84 Pass-Minor 1/10- 07-07A-07-07A-07-07A 3,101.14 3,115.00 47.70 96.01 -46.96 FAIL-Major Risk 07-07A-07-079-07-079 3,101.14 3,115.00 47.70 96.12 -47.07 FAIL-Major Risk 07-08-07-08-07-08 2.944.40 2,960.00 106.81 79.85 35.90 Pass-Major Risk 07-08-07-08A-07-08A 2,944.40 2,960.00 106.81 79.85 35.90 Pass-Major Risk 07-08-07-08B-07-08B 2,943.18 2,950.00 106.61 79.51 35.90 Pass-Major Risk 07-09-07-09-07-09 2,961.79 2,990.00 227.71 82.45 150.46 Pass-Major Risk 07-09-07-09A-07-09A 2,961.79 2,990.00 227.71 82.45 150.46 Pass-Major Risk 07-10-07-10-07-10 3,100.00 3,155.00 370.17 126.58 258.02 Pass-Major Risk 07-10-07-10A-07-10A 3,100.00 3,155.00 370.17 126.58 258.02 Pass-Major Risk 07 11 07 11 07 11 3,100.00 3,170.00 499.65 142.24 369.80 Pass-Major Risk 07-11-07-11A-07-11A 3,100.00 3,170.00 499.65 142.24 369.80 Pass-Major Risk 07-15-07-15-07-15 4,164.36 4,015.00 370.80 181.38 190.82 Pass-Major Risk 07-15-07-15A-07-15A 4,164.36 4,015.00 370.80 181.38 190.82 Pass-Major Risk 07-16-07-16-07-16 3,853.88 3,625.00 502.29 158.25 365.97 Pass-Major Risk 07-16-07-16A-07-16A 3,853.88 3,625.00 502.29 158.25 365.97 Pass-Major Risk 07-17-07-17-07-17 4,126.75 3,820.00 568.53 182.56 431.78 Pass-Major Risk 07-18-07-18-07-18 7,427.90 7,085.00 387.45 345.87 42.87 Pass-Major Risk 07-19-07-19-07-19 2,695.82 2,640.00 1,010.66 59.49 958.39 Pass-Major Risk 07-19-07-19A-07-19A 2,695.82 2,640.00 1,010.66 59.49 958.39 Pass-Major Risk 07 20 07 20 07 20 4,110.47 3,730.00 638.90 176.21 516.05 Pass-Major Risk 07-20-07-20A-07-20A 4,110.47 3,730.00 638.90 176.21 516.05 Pass-Major Risk 07-20-07-20B-07-209 4,110.47 3,730.00 638.90 176.21 516.05 Pass-Major Risk 07-21-07-21-07-21 4,597.53 4,365.00 290.25 164.09 126.14 Pass-Major Risk 07 22 07 22 07 22 3,915.41 3,580.00 783.12 163.77 634.16 Pass-Major Risk 07-22-07-22A-07-22A 3,915.41 3,580.00 783.12 163.77 634.16 Pass-Major Risk 07-25-07-25-07-25 2,690.87 2,715.00 468.02 39.44 428.72 Pass-Major Risk 07-25-07-25A-07-25A 2,690.87 2,715.00 468.02 39.44 428.72 Pass-Major Risk 07-26-07-26-07-26 2,693.79 2,715.00 364.76 43.31 321.53 Pass-Major Risk 10/22/2014 12:01:08PM Page 3 of 5 COMPASS 5000.1 Build 61 • • BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-07A Project: Prudhoe Bay TVD Reference: 07-07C @ 60.87usft(D14 plan) Reference Site: PB DS 07 MD Reference: 07-07C @ 60.87usft(D14 plan) Site Error: 0.00usft North Reference: True Reference Well: 07-07A Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan 07-07C Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: Plan#2b 07-07C Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 07 07-27-07-27-07-27 3,592.03 3,410.00 627.12 156.53 481.05 Pass-Major Risk 07-32-07-32-07-32 3,116.52 3,165.00 432.46 131.24 306.53 Pass-Major Risk 07-32-07-32A-07-32A 3,116.52 3,165.00 432.46 131.24 306.53 Pass-Major Risk 07-32-07-32APB 1-07-32APB1 3,116.52 3,165.00 432.46 131.24 306.53 Pass-Major Risk 07-32-07-32B-07-32B 3,116.52 3,165.00 432.46 131.07 306.71 Pass-Major Risk 07-32-07-32PB1-07-32PB 1 3,116.52 3,165.00 432.46 131.23 306.54 Pass-Major Risk 07-33-07-33-07-33 2,711.67 2,690.00 1.244.57 56.64 1,190.05 Pass-Major Risk 07-33-07-33A-07-33A 2,711.67 2,690.00 1,244.57 56.79 1,189.89 Pass-Major Risk 07-33-07-33APB1-07-33APB1 2,711.67 2,690.00 1.244.57 56.64 1,190.05 Pass-Major Risk 07-33-07-33APB2-07-33APB2 2,711.67 2,690.00 1,244.57 56.64 1,190.05 Pass-Major Risk 07-33-07-33B-07-33B 2,711.67 2,690.00 1,244.57 56.79 1,189.89 Pass-Major Risk 07-34-07-34-07-34 2,709.44 2,670.00 1,201.54 54.33 1,148.97 Pass-Major Risk 07-34-07-34A-07-34A 2,709.44 2,670.00 1,201.54 54.33 1,148.97 Pass-Major Risk 07-34-Plan 07-34B-Plan#2 07-34B 7,626.37 7,455.00 446.10 349.10 100.34 Pass-Major Risk 07-35-07-35-07-35 5,000.30 4,720.00 263.65 156.34 107.36 Pass-Major Risk 07-35-07-35A-07-35A 5,000.30 4,720.00 263.65 156.18 107.52 Pass-Major Risk 07 36 07 36 07 36 4.595.49 4,050.00 1.524.27 203.91 1,422.73 Pass-Major Risk 07-37-07-37-07-37 3,345.78 3,355.00 761.42 160.97 600.97 Pass-Major Risk 10/22/2014 12.:01:08PM Page 4 of 5 COMPASS 5000.1 Build 61 S Project: Prudhoe Bay Site: PB DS 07 • Well: 07-07A Wellbore: Plan 07-07C Design: Plan #2 07-07C From Colour To MD 0 2400 From 2450'md (300'md above planned KOP)to 9500'md (T') 2400 2750 Scan interal 25 ft 2750 3000 Scale 1 inch : 50ft 3000 4000 Several wells fail the major risk 4000 _. 5000 Wells pass risk rules See AC summary report for details 5000 — 6000 o� oy 6000 — 7000 - ,� 0 7000 8000 o��o Ko 0150 8000 - 9000 Ka��4/� 9000 9500 330 iii*e Witt y'\ 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I m �o•,;`0 3-1/8"5000 lIIIIII;Frapl r", • Davies, Stephen F (DOA) From: Gorham, Bradley M <Bradley.Gorham@bp.com> Sent: Tuesday, October 28, 2014 4:24 PM To: Davies, Stephen F (DOA) Subject: RE: PBU 07-07C (PTD#214-175): Permit to Drill Question Attachments: 07-07C (P2b) approved directional report.pdf Steve, I have attached the final approved directional plan for 07-07C. It contains the vertical section diagram that you requested. If you need any other information or have any other questions don't hesitate to contact me. Thanks, Brad Brad Gorham BP Exploration (Alaska), Inc. Drilling Engineer W: (907)564-4649 C: (907)250-3209 Bradley.Gorham@bp.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, October 28, 2014 3:54 PM To: Gorham, Bradley M Subject: PBU 07-07C (PTD #214-175): Permit to Drill Question Bradley, Could BP please provide directional survey plan and vertical section diagrams for the proposed PBU 07-07C development well? The directional survey station data were provided, but the accompanying diagrams are missing from the application package. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: 7 ( f i� "- >7C PTD: 2-IV / 75---. /'Development Service Exploratory Stratigraphic Test Non-Conventional FIELD:- ,r.' Zel-e---- o'A POOL: '1.-1. C')/ / Check Box for Appropriate etter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. 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